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Home My WebLink About167-0581a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 92' (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 20" B-40/H-40 329 13-3/8" K-55/J-55 1,980 9-5/8" S-95/N-80 10,070 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 9,372/8,991 8,724 8,663 2-7/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6/4/2023 167-058 / 323-108 50-733-20047-00-00 S MGS Unit 04 ADL0018746 741' FSL, 1823' FWL, Sec 35, T8N, R13W, SM, AK 1788' FNL, 2120' FWL, Sec 35, T8N, R13W, SM, AK N/A 10/27/1967 10,550 / 10,103 LS:Surface/ SS: 139'/139' 100' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229270.3215 2463914.3386 N/A CASING WT. PER FT.GRADE 12/10/1967 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2466657.1614 TOP HOLE SIZE AMOUNT PULLED N/A 229628.2537 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) 9,330/8,951 PACKER SET (MD/TVD) 2-7/8" Surf Surf 1,999Surf Surf 40 & 43.5 Surf 85 & 95 54.5 & 61 329 Surf 10,515 N/A N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Middle Ground Shoal / MGS Oil N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by James Broos on 6/23/2023 at 2:58PM Abandoned 6/4/2023 JSB RBDMS JSB 062723 xGDSR-7/19/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A N/A N/A Top of Productive Interval N/A N/A N/A N/A 31. List of Attachments: Wellbore schematic, Well operations summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Aras Worthington Digital Signature with Date:Contact Email:Aras.Worthington@hilcorp.com Contact Phone: 907 564-4763 Operations Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS INSTRUCTIONS Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.06.23 14:49:33 - 08'00' Dan Marlowe (1267) 20” 329’ 13-3/8” 1,995’ 13϶ 9-5/8” 10,515’ PBTD = 10,467’ MD & 10,022’ TVD TD = 10,550’ & 10,100’ TVD Hole angle thru int. = 18.5Û Lease: SMGS 18746 Well: Di-04 API #: 50-733-20047-00 PTD: 167-058 Leg 1, Slot 2 Mud Line MSL RKB 102’ Size Type Wt/Grade/Conn I.D. Top Shoe Cmt sx TOC 33" Structural ? ? Surf ? Drive n/a 20" Conductor 85 & 96# B-40 & H-40 19" ? Surf 329' 625 / 128 Bbls calc. surf 13-3/8" Surface 54.5 & 61# K-55 & J-55 12.615"/ 12.515" Surf 1,999' 1,822 / 373 Bbls calc. surf 9-5/8" Production 40 & 43.5# S-95 & N-80 8.835"/ 8.755" Surf 10,515' 1,450 / 297 Bbls 8,702' CBL Casing Detail Completion Jewelry Detail Depth Length I.D. O.D. 34.15' 8,671' 2.25" - 8,691' 2.50" - 8,692' 2.441" - 8,724' - 3.00" - 34.15' 8,661' 1.995" - 8,663' 1.995" - 9330' 0" 15' 9372' 0" Long String (Power Fluid) 2-7/8", 6.4#, L-80, Butt Short String (Production) 2-7/8", 6.4#, L-80, Butt Description CIW Dual Hanger KOBE 2-1/2" "ALP" Dbl Parallel Cavity 2-7/8" 8rd box x 2-7/8" Buttress pin 15' Cemented Pup 9-5/8" "BWD" Perm Pkr w/15' cemented Pup 1 joint 2-7/8" 6.4# L-80 Buttress SC Mule Shoe'd 2-7/8" tbg jt w/butt box CIW Dual Hanger Cross Over: 2-7/8" Butt Box x 2-3/8" 8rd Pin Pup joint, 2-3/8", 4.6#. L-80, Buttress Baker Model "D" Production Packer Top Btm ft / SPF 8,795' 8,900' 65' / 4 9,125' 9,315' 105' / 4 9,425' 10,060' Isolated by Pkr. Open f/production. Comments New New Perforations: TT 8,682’ ELM Pkr9,330’ Fill 9,328’ Tubing punch 8,652’ – 8,658’ 50 B b l K c l 50 B b l K c l 118’ 34’RKB - Tbg Hgr CBL TOC = 8,702’ Pkr9,372’ Perfs 8795’ – 9315’ Perfs 9425’ – 10060’ 8/2011 – Well circulated with 9.8 ppg brine. Place LCM pill and squeeze 1 bbl into perfs. Freeze protected. 8/16/07 – RIH on LS - Tandem gauges to 9300’ 6/26/06 – RIH on LS w/2” GR to 9319’ 9/12/00 – RIH on LS, attempt to pull pump – unable to pull and left junk on top of pump. 3/4/00 – RIH on SS w/2.34” GR to 8662’. Tubing punch 8652’ - 8658’ ** 2005 – Able to pump down LS/up SS but unable to pump down SS. ** Historically high norm readings from Kobe cavities when pulled. G&G Top Oil 8800’ Cement plug #1: TBG Punch SS: 8542-45’ MD LS: 2629’ SLM to ~8724’ MD SS: 2763’ SLM to ~8724’ MD IA: 3000’ MD (Est.) - ~8724’ MD Cement plug #2: TBG Punch LS & SS: 2493-96’ MD LS: 2500’ to 1297’ MD SS: 2500’ to 139’ IA: 2500’ to ~1848’ MD Cement plug #3: LS, IA, & OA: 500’ MD to surface OOA: Cemented to surface and squeezed from ~500’ MD Rig Start Date End Date EL / SL / Cement Pump 5/21/23 6/20/23 Safety Meeting- Pressure testing, working with E line crew. Work on DI-9. Pressure test with AOGCC Sully Pressure test LS, Initial 1780 psi, @15min 1726 psi, @30 min 1708 psi, good test. Rig up E line, Run in LS tag bottom @ 1297', pull up to 500', set 2" x 3' charges, POOH, Rig up to establish circulation down LS, out IA,OA @ 2 bbl./min @ 150 psi, OOA pressured up to 400 with 1.5 bbl. pumped,-no circulation, rig down E-line crew. Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 04 50-733-20047-00-00 167-058 Daily Operations: 05/28/2023 - Sunday Safety meeting-working with wireline and crane operations. Move E line unit to work on DI-4 and DI-9, Rig up E line, RIH in LS, bailer, jars and weight bar, Tag cement @ 1300', POOH with cement sample, cement sample was sloppy not hard, Rig up to pre-test LS, start 1764 psi, @ 15 min 1729 psi, @ 30 min 1717 psi-good test. 05/22/2023 - Monday Safety Meeting- cementing working with crane. Finish Mixing KCL, line cuttings bin with plastic for cement returns, finish rigging up cement lines on DI-4, make up mix water for cement. Safety Meeting -Cementing. Fill lines to pressure test, Upper and lower well head valves failed on SS. Work seized valves free, test against upper valve on SS failed, test against Lower valve held @ 1500. Decision was made to cement in AM. Unload cement silos and pallets off boat and spot on deck. 05/21/2023 - Sunday Finish up DI-11. Rig up cement package on DI-4, set cuttings bin, mix 9.8 brine. 06/01/2023 - Thursday R/U circ lines, pump down LS out IA good, pump down LS out OA 1 BPM 500psi, found bad valve on OA replace same. Pumped down OOA pressured up t/500psi w/4 bbls, shut down bled t/150psi, in one min, spotted 30bbls wash in IA, spotted 20 bbls wash in OA @ 2bpm 100psi. 05/29/2023 - Monday Rig Start Date End Date EL / SL / Cement Pump 5/21/23 6/20/23 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 04 50-733-20047-00-00 167-058 Daily Operations: 06/19/2023 - Monday R/u EL on SS, RIH with 1.75" bailer and tag TOC @ 139'md. W/t POOH no sample recovered. R/d EL. 06/20/2023 - Tuesday Verified TOC, OOA-TOC visual at surface, OA-TOC visual at surface, IA-TOC visual at surface, LS-TOC visual at surface, SS- TOC was tagged at 139'md. 06/04/2023 - Sunday Prep to cement well Di-04. R/u chicksan to LS, IA, OA, OOA. Pre-job. Broke circ. dwn LS up OA, return almost immediate. PT t/1000psi on lines (not well)-good. Pmp 35bbl cement dwn LS and up OA, good cement returns seen at surface. Swap to take returns up the IA, but returns did not clean up just cement. Verify line up-good. Swap to pump up OA-pre-wash water returns. Swap to up IA, pre-wash return then to cement. Swap to up the OA and IA, cement returns. Swap back to pump up the OA-pmp pressured out @500psi. Swap to pmp up IA-cement returns. Shut-in well and call Engineer, decision to up 500psi pressure limit to 900psi to try and establish circ. thru OA as we think AO plugged when we first started pumping 35bbl cement and that there is communication between the OA and IA up close to surface as cement returns came back at 35bbls while pumping the OA(tbg vol=3bbl, OA vol=31.5bbl, IA vol=30bbl). Pmp 2bbl cement to confirm good cement in IA. Swap to pmp up the OA, pressure up, worked rate up to .9bpm / 600psi getting clean pre-wash returns for 32bbl pumped- good cement returns seen at surface. Swapped line up to pmp dwn LS and up the OOA, pressured up to 300psi with 3bbl, squeezed 5x at 500psi. Shut in tree and wellhead and washed lines to cuttings boxes. R/D chicksan from Di-04 and R/U on Di-09, line up to pmp dwn the tbg and up the OOA, pressured up-no injectivity. Swap to pmp dwn tbg and up the OA, circ. B/U 2x (70bbl) and spot 10bbl pre-wash on the backside. Swap to pmp dwn tbg and up the IA, circ. (36bbl) and spot 10bbl pre-wash on the backside. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:35 Township:8N Range:13W Meridian:Seward Drilling Rig:N/A Rig Elevation:N/A Total Depth:10550 ft MD Lease No.:ADL 0018746 Operator Rep:Suspend:P&A:XXX Conductor:20"O.D. Shoe@ 329 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 1999 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production 9 5/8"O.D. Shoe@ 10515 Feet Csg Cut@ Feet SS Tubing:2 7/8"O.D. Tail@ 8663 Feet Tbg Cut@ Feet LS Tubing:2 7/8"O.D. Tail@ 8724 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified LS Tubing Fullbore Bottom 10550 ft 1300 ft Wireline tag SS Tubing Fullbore Bottom 10550 ft Surface Initial 15 min 30 min 45 min Result Tubing 1780 1726 1708 IA 0 0 0 OA 0 0 0 Remarks: Attachments: Tag top of cement in long string tubing at 1300 ft; wet cement in bailer May 27, 2023 Sully Sullivan Well Bore Plug & Abandonment S MSG Unit Dillon 4 Hilcorp Alaska LLC PTD 1670580; Sundry 323-108 Photos (2) Test Data: Casing Removal: Walter Waite Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): P rev. 11-28-18 2023-0527_Plug_Verification_SMGS_Di-04_ss                Plug Verification - SMGS Dillon-4 (PTD 1670580) 5/27/2023 Short String Tubing Cement to Surface Short String Tubing Cement Sample from Bailer JLC 3/29/2023 RBDMS JSB 030323 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Aras Worthington To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] SMGS-04 (PTD 167-058) P&A sundry comments Date:Friday, March 3, 2023 10:06:07 AM Attachments:February 2023_Dillon Tubing and Casing Pressures.pdf Dillon Dec 2022 Well Head Pressure Readings.pdf Dillon January 2023 Well Pressures.pdf Bryan, Thanks for the thorough review and commentary. Attached are the field sheets for the Dillon well pressure reads performed this winter. The only bleeding that was done on Dillon wells this winter was on Di-02 SS, which turned out to be a bad gauge pegged at 90 psi. My understanding is that there was some pressure behind the gauge which was bled down to replace it. The gauge was replaced in December. Additional responses to your questions/comments are below. Thanks, Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, March 2, 2023 5:43 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: [EXTERNAL] SMGS-04 (PTD 167-058) P&A sundry comments Aras, I’ve had a chance to review this sundry application and the one for MGS-16 and have a few comments. 1. I’m in agreement with the plan to tag the plugs and forego the pressure testing requirement since the reservoir plug did not show any pressure build-up over the winter season. Please submit the pressure that’s been collected since the freeze protection was pumped last fall and include any bleeding activity that took place, if any. I’ll include the data in the sundry. I have Josh’s spreadsheet, but it’s not annotated with any bleed information. 2. For step #2, after circulating cement up into the IA, there will be some uncertainty about how much cement is lost to the perfs during the circulation, but it’s an opportunity to squeeze some cement outside the perfs and potentially mitigate the slow OA and OOA repressurization. I’ve added a couple conditions to the sundry based on the following: a. In order to estimate TOC in the IA you need to monitor fluid returns and losses. I’ve added a requirement to report fluid losses on the 10-407. Understood. We always have the WSS keep track of return volumes on these cement jobs and report them in the job summary to track losses and estimate TOC, so it will be in the 407 regardless. b. When you circulate cement to surface on the Short String, you’ll be applying squeeze pressure to the perfs and have some U-tube effect between SS and IA/LS. That means that the fluid level in the SS is likely to fall as the cement is squeezed away. There will be a U-tube effect between SS and IA/LS with ~570 psi differential, so you will be able to see if that pressure drops off before cement sets. If pressure falls off, you’ll know that SS TOC is dropping. The effect is greater on MSGS-16 due to the longer cement column and greater U-tube differential. Understood and agreed. c. I’ve added a requirement to tag TOC in both LS and SS to confirm you still have cement to surface everywhere. Understood and agreed. 3. In step #6, I can’t remember if Dillon 4 exhibited IAxOA communication during the diagnostic testing, but it wouldn’t surprise me since the pressures are tracking closely. I’d like to see one step added to take advantage of a possible shallow leak in the 13-3/8” csg and potentially top off the OOA with cement: After circulating cement to surface up the OA, switch back to take returns up the OOA again to see if you can squeeze cement out of the OA into the OOA and to surface. I’m Open to discussion on this. Understood and agreed. The highlighted step below was intended to cover this, and is our standard practice on these surface cement jobs: Always SI all annuli except the OOA and squeeze to 500 psi at the end. Di-04 did not show any OA x OOA pressure communication during the diagnostic work last year (500 psi/5-min PTs of both, separately) but it is of course still possible there is very slow communication over time. But it’s not something I would expect we could squeeze any cement into. Still, we will try as we always do on the surface cement jobs. 6. Pump LS x IA x OA x OOA surface cement plug as follows: 50 bbls surfactant wash down LS and out OOA (if circulation is established out OOA) i. When 18 bbls are away swap to taking returns from the OA ii. When 33 bbls are away swap to taking returns from the IA 62 bbls 12 - 15.8 ppg Class G cement i. Circulate up the OOA until good cement returns are seen at surface (if circulation up OOA is established) ii. Circulate up the OA until good cement returns are seen at surface iii. Circulate up the IA until good cement returns are seen at surface iv. SI all annuli except the OOA and squeeze to 500 psi v. Mix on the fly and pump excess cement as needed to get good cement returns across all annuli Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Punch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,550 feet See schematic feet true vertical 10,103 feet See schematic feet Effective Depth measured 2,629 LS 2,763 SS feet 9,330 & 9,372 feet true vertical 2,593 LS 2,721 SS feet 8,951 & 8,991 feet Perforation depth Measured depth See schematic feet True Vertical depth See schematic feet 2-7/8" SS 6.4# / N-80 8,663 (MD) 8,324 (TVD) Tubing (size, grade, measured and true vertical depth) 2-7/8" LS 6.4# / N-80 8,724 (MD) 8,381 (TVD) BWD Perm Pkr 9,330 (MD) 8,951 (TVD) Packers and SSSV (type, measured and true vertical depth) Model D Pkr 9,372 (MD) 8,991 (TVD) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:N/A 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 0 322-371 & 322-630 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Aras Worthington Aras.Worthington@hilcorp.com 907 564-4763Operations Manager N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD N/A 0 Size 329 0 00 0 00 13-3/8" 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 167-058 50-733-20047-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018746 Middle Ground Shoal / Middle Ground Shoal Oil S MGS Unit 04 Plugs Junk measured Length measured TVD Production Liner 10,515 Casing Structural 10,07010,515 329 1,999 329Conductor Surface Intermediate 20" 3,090psi 3,090psi 5,750psi 1,999 1,999 Burst Collapse 1,540psi pp kk tt Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Anne Prysunka at 8:36 am, Dec 08, 2022 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.12.07 20:15:29 -09'00' Dan Marlowe (1267) 20 329 13-3/8 1,995 13 9-5/8 10,515 PBTD = 10,467 MD & 10,022 TVD TD = 10,550 & 10,100 TVD Hole angle thru int. = 18.5 Lease: SMGS 18746 Well: Di-04 API #: 50-733-20047-00 PTD: 167-058 Leg 1, Slot 2 Mud Line MSL RKB 102 Size Type Wt/Grade/Conn I.D. Top Shoe Cmt sx TOC 33" Structural ? ? Surf ? Drive n/a 20" Conductor 85 & 96# B-40 & H-40 19" ? Surf 329' 625 / 128 Bbls calc. surf 13-3/8" Surface 54.5 & 61# K-55 & J-55 12.615"/ 12.515" Surf 1,999' 1,822 / 373 Bbls calc. surf 9-5/8" Production 40 & 43.5# S-95 & N-80 8.835"/ 8.755" Surf 10,515' 1,450 / 297 Bbls 8,702' CBL Casing Detail Completion Jewelry Detail Depth Length I.D. O.D. 34.15' 8,671' 2.25" - 8,691' 2.50" - 8,692' 2.441" - 8,724' - 3.00" - 34.15' 8,661' 1.995" - 8,663' 1.995" - 9330' 0" 15' 9372' 0" Long String (Power Fluid) 2-7/8", 6.4#, L-80, Butt Short String (Production) 2-7/8", 6.4#, L-80, Butt Description CIW Dual Hanger KOBE 2-1/2" "ALP" Dbl Parallel Cavity 2-7/8" 8rd box x 2-7/8" Buttress pin 15' Cemented Pup 9-5/8" "BWD" Perm Pkr w/15' cemented Pup 1 joint 2-7/8" 6.4# L-80 Buttress SC Mule Shoe'd 2-7/8" tbg jt w/butt box CIW Dual Hanger Cross Over: 2-7/8" Butt Box x 2-3/8" 8rd Pin Pup joint, 2-3/8", 4.6#. L-80, Buttress Baker Model "D" Production Packer Top Btm ft / SPF 8,795' 8,900' 65' / 4 9,125' 9,315' 105' / 4 9,425' 10,060' Isolated by Pkr. Open f/production. Comments New New Perforations: TT 8,682 ELM Pkr9,330 Fill 9,328 Tubing punch 8,652 8,65850 Bbl Kcl50 Bbl Kcl118 34RKB - Tbg Hgr CBL TOC = 8,702 Pkr9,372 Perfs 8795 9315 Perfs 9425 10060 8/2011 Well circulated with 9.8 ppg brine. Place LCM pill and squeeze 1 bbl into perfs. Freeze protected. 8/16/07 RIH on LS - Tandem gauges to 9300 6/26/06 RIH on LS w/2 GR to 9319 9/12/00 RIH on LS, attempt to pull pump unable to pull and left junk on top of pump. 3/4/00 RIH on SS w/2.34 GR to 8662. Tubing punch 8652 - 8658 ** 2005 Able to pump down LS/up SS but unable to pump down SS. ** Historically high norm readings from Kobe cavities when pulled. G&G Top Oil 8800 Cement plug #1: TBG Punch SS: 8542-45 MD LS: 2629 SLM to ~8724 MD SS: 2763 SLM to ~8724 MD IA: 3000 MD (Est.) - ~8724 MD LS & SS Perforated: 2493-96 MD Rig Start Date End Date SL 8/21/22 11/8/22 09/01/2022 - Thursday Spot and R/u Unit, built tbg puncher and assemble tools, Stab on lubricator on SS and PT 250/2500psi-good Well pressures, LS/SS/IA=0/0/100. RIH on SS w/ 2 x wt/bar, ccl, 3' x 1-9/16" Tbg puncher, Tag btm of tool string @ 8,553', log collar @ 8,546', pressured up SS t/100psi fired Tbg puncher @ 8542'-45'. POOH. L/d tool string. Confirmed puncher fired. R/u circ eq. Pumped down LS returns up SS, established circulation @ 2bpm/500psi. Circulated B/u w/good returns. SD pump. R/d EL and circ eq. Released AKE-line crew. 08/29/22 - Monday R/u SL, PT t/2500psi. RIH on SS w/1.75 DD Bailer t/8578'kb w/t to 8582'kb. POOH recovered small fibrous debris. R/d move to Di-7 08/21/22 - Sunday Held JJSM and approve PTW Service and warm up eq. D-17, Injected 702bbls returns from H-1 and H-2 tanks @ 3.5bpm/3000psi, loaded empty silos on boat and take to beach to be filled. Well pressure LS/SS/IA= 120/0/105, R/u circulating lines to Di-4, Pumped down LS returns up IA, returns 32bbls diesel/oil then brine 9.3ppg brine. Swapped returns to SS, pumped 5bbls returns 9.8 Brine SD pump. RD HAL cement pump, Held PJSM, PT lines t/3200psi good test, lined up dn LS returns up IA, pumped 20bbls of Mud Wash followed by 50bbls of 9.8 Brine @ 3bpm/1000psi, swapped returns from IA to the SS, pumped 9bbls and lost returns. SD pump. Began troubleshooting, Lined up to pumped down SS, worked pump pressure up t/2500psi and surging well no luck, make several attempts to pump both direction no luck. Secured well SDFN. Work boat arrived, off load cement solos. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 04 50-733-20047-00-00 167-058 Rig Start Date End Date SL 8/21/22 11/8/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 04 50-733-20047-00-00 167-058 09/09/22 - Friday Slick line arrived on location, fill out permits, spotted equipment, rig up slick line on short string, P/test lubricator to 250 low and 3000 psi. RIH with 2.25" dd bailer to 2763' kb. tag with tools, AOGCC Brian Bixby, witness tag, pooh fluid only in bailer. Move to long string side. pressure test lubricator to 250 low and 3000 psi RIH with 2.25" dd bailer to 2629'kbtag with tools, AOGCC witness tag pooh had 6" of contaminated cmt. rig down slick line. CMIT - LS X SS XIA to 2500 psi per sundry Pretest: LS/SS/IA/OA/OOA = 0/0/24/50/12 BBL Pump: 2.0 Initial: LS/SS/IA/OA/OOA = 2817 / 2817/ 2817/165/12 15 MIN: LS/SS/IA/OA/OOA =2616/2616/2616/155/12 30 MIN: LS/ SS/IA/OA/OOA = 2485/2485/2485/145/12 Re pressure up to 2827 psi Initial LS/SS/IA/OA/OOA = 2827/2827/2827/165/12 15 MIN; LS/SS/IA/OA/OOA = 2707/2707/2707/160/12 30 MIN; LS/SS/IA/OA/OOA = 2611/2611/2611/150/12 45 MIN: LS/SS/IA/OA/ OOA = 2521/2521/2521/125/12 BLEED OFF PRESSURE. TEST FAILED witness by AOGCC Brian Bixby 09/03/2022 - Saturday Held PJSM, approve PTW, Service and warmed eq. Well pressures, LS=80/SS=0/IA=80/OA=20/OOA=0 R/u flanges and circulating eq. to LS,SS and IA. HAL cement crew arrived, orientate crew. Serviced the cement pump, rolled the the HR5 tanks. Held PJSM, R/u Hal cement eq. lined up valves to pump down LS, returns up IA, pumped 5bbls away verify circulation, PT lines to 300psi/3400psi, good test. Pumped 20bbls of Mud Flush, followed by 50bbls of 9.8 brine, swapped returns up SS, pumped away 18bbls, swapped returns back to IA, pumped 129bbls of 9.8 brine @ 3.5bpm/900psi. Mix and pumped 406bbls of 14ppg Cement @ 5bpm/1550psi, at 390bbls away swapped returns to SS, pumped 16bbls away, pumped wiper ball and displaced cement w/ 17.5bbls of 9.8 brine. Held 400psi on choke while pumping job. Calculated Job Vol: 434.5bbls Job Vol Returned: 424bbls. Preformed sheen test (no sheen) washed up equipment with 21bbls overboard. Locked out overboard line, Mixed HRS water in Tank 3. Injected 175bbls of brine/diesel from Di-4 returns. Rig Start Date End Date SL 8/21/22 11/8/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 04 50-733-20047-00-00 167-058 Rig up to combo MIT LS, SS, IA to 2600 psi. Start 2794 5 min 2774 10- 2756 15-2740 20-2725 25-2710 30-2697 35-2684 40-2672 45-2660 50-2649 55-2638 60-2627 10/05/2022 - Wednesday Combo MIT SS, LS, IA 2600 psi. This was a SIMOPS . Wasn't able to get readings every 5,10,15,20,30 due to personnel availability . Grystal gauge chart recording was sent to town. 10/06/2022 - Thursday Fluid pack lines CMIT - LS x SS X IA to 2500 psi as per sundry Pretest press: LS/SS/IA/OA/OOA _ 15/15/15/50/12 BBls pumped 2.5 Initial LS/SS/IA/OA/OOA = 2812/2812/2812/165/12 15 min= LS/SS/IA/OA/OOA= 2679/2679/2679/156/12 30 min= L/S/SS/IA/OA/OOA = 2579/2579/2579/150/12 45 min= LS/SS/IA/OA/OOA = 2494/2494/2494/2494/145/12 bbL return 2.5 AOGCC Brian Bixby witness test 09/10/22 - Saturday Rig Start Date End Date SL 8/21/22 11/8/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 04 50-733-20047-00-00 167-058 11/05/22 - Saturday Held PJSM. R/u EL on LS, M/u 2" x 3' perf gun with production charges, stab on lubricator and PT 250/2500psi. RIH w/perforator logged collars, stopped @ 2490'CCL depth. Perforated LSxSSxIA 2493'-96'. POOH confirmed gun fired. R/d EL. R/u circ eq. Pumped 10bbls away at 3bpm/450psi dn LS returns up IA, swapped returns to LS pumped away 10bbls @ 3bpm/500psi. SD pump. R/d and blew dry circ eq. AOGCC witnessed By Inspector Brian Bixby, CMIT SS, LS, IA Initial 2739 15 min 2681 30 min 2635 45min 2596 OA pre test 65 Initial 175 15 min 170 30 min 170 45min 166 BBLS in 1.7 BBls out 1.6 10/31/22 - Monday R/u EL, M/u 1-11/16"RCBL, stab on well and PT lubricator 250-2500psi;RIH w/RCBL and tagged @ 2795', POOH logging did not see cement. R/d EL 10/23/22 - Sunday 10/07/2022- Friday Rig up digital recorder. Perform MIT on LS, SS, IA combo to 2600 psi. Started 2600 psi on the mechanical gauge 0 min 2600 5 min 2577 (23 psi loss) 10 min 2560 ( 17 psi loss) 15 min 2555 (5 psi loss) 30 min 2503 (52 psi loss) 45 min 2469 (34 psi loss) Rig Start Date End Date SL 8/21/22 11/8/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 04 50-733-20047-00-00 167-058 11/08/22- Tuesday R/u circulating eq. Circulated in 7bbls of diesel down IA and 1 bbl down SS and LS to freeze protect to 120' below wellhead. R/d circ eq. 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Subject:RE: [EXTERNAL] RE: Dillon 04 (PTD 167-058) Date:Friday, November 4, 2022 12:31:00 PM Aras, Shooting holes in the casing and tubing will provide an opportunity to monitor for pressure from outside casing and potentially squeeze cement outside the casing in the future. It also provides opportunity to pump the required freeze protection into the two tubing strings and Inner Annulus. Hilcorp has verbal approval to proceed with the perforation at +/-2500’ MD and establish circulation per the Sundry application submitted on 10/31/22, (steps 4, 5 and 6 only) for the purpose of freeze protecting and monitoring pressures. Placing the cement plugs is not approved at this time, but may be approved after further discussion and observation of the well. FYI, this Sundry has been assigned sundry number 322-630. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Friday, November 4, 2022 11:44 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Dillon 04 Bryan, That was a mistake/carry-over from the previous revision where we were deliberately perforating the 9-5/8” casing to get communication to the OA. In this case, at 2500’ MD we still want to perforate so that we can shoot from the LA into the SS to get communication. And naturally that will perforate the 9-5/8” casing as well. But, it shouldn’t make any difference to the P&A having holes in the 9-5/8” casing at that depth since it will all be buried in cement. Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, November 4, 2022 11:27 AM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: Dillon 04 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. What is the reason for perforating the 9-5/8” casing at 2500’? Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Friday, November 4, 2022 11:14 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] RE: Dillon 04 Bryan, Understood on all points, however if we get approval to perforate/punch where the current revision indicates (@~2500’MD), we can still change our minds and decide to perforate again up above the OA shoe (~1800’ MD) and get the OA cemented as deep as possible per the previous revision. If we punch/perforate now @ ~2500’ MD we can at least freeze-protect the well. And we still leave all options open on how to proceed with the P&A. Thanks for your consideration. Aras From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, November 4, 2022 10:37 AM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: [EXTERNAL] RE: Dillon 04 I’m going to have to discuss this approach with folks around here. Dillon 4 is different than Dillon 9 in that it has sustained casing pressure on the OA after pumping the primary cement job. As we discussed, it may be better in this case to place cement as deep as possible in the OA, similar to your original proposal, but I need to discuss this internally. Bryan McLellan Senior Petroleum Engineer CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Aras Worthington <Aras.Worthington@hilcorp.com> Sent: Friday, November 4, 2022 7:20 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: Dillon 04 Bryan, Thanks again for the expedited approval on Di-09. We know you’re working on Di-04, but if we can’t get full approval for the revised Sundry today can we get a verbal approval to perforate the LS x SS (and/or punch the SS if needed) today? We have EL coming out today. Thanks again, Aras Worthington Hilcorp Alaska LLC Senior Technical Advisor for Alaska Operations Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 35 Township: 8N Range: 13W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 10550 ft MD Lease No.: ADL 0018746 Operator Rep: Suspend: P&A: XXX Conductor: 20" O.D. Shoe@ 329 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 1999 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production 9 5/8" O.D. Shoe@ 10515 ft Feet Csg Cut@ Feet SS Tubing: 2 7/8" O.D. Tail@ 8663 ft Feet Tbg Cut@ Feet LS Tubing: 2 7/8" O.D. Tail@ 8724 ft Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Pre-Test Initial 15 min 30 min 45 min Result Tubing 11 2739 2681 2635 2596 IA 11 2739 2681 2635 2596 OA 65 175 170 170 166 Remarks: Attachments: Harold Soule Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I Top of cement tags completed 9/9/2022. Long and Short Tubing strings were twinned in with the IA for the test. Pressure loss was -58 psi / -46 psi / -39 psi. I told the company rep that town would make the pass-fail call.1.7 bbls in, 1.6 bbls returned. September 23, 2022 Brian Bixby Well Bore Plug & Abandonment S MSG UNIT Dillon 4 Hilcorp Alaska LLC PTD 1670580; Sundry 322-371 none Test Data: Casing Removal: rev. 11-28-18 2022-1023_Plug_Verification_SMGS_Di-04_bb 9 9 9999 9 9 9 9 9 9 9 9 ) 7HVWUHVXOWFKDQJHGWR)$,/GRHVQRWPHHW$2*&&FULWHULDIRU SUHVVXUHORVVWUHQGLQJWRZDUG]HURSVLWRWDOSUHVVXUHORVVIRU PLQLQWHUYDOIRUPLQLQWHUYDO-5HJJ$2*&&,QVSHFWLRQ 6XSY Top of cement tags completed 9/9/2022. Pressure loss was -58 psi / -46 psi / -39 psi. pgp James B. Regg Digitally signed by James B. Regg Date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ames B. Regg Digitally signed by James B. 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Regg Digitally signed by James B. Regg Date: 2022.09.19 14:46:58 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Aras Worthington To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] SMGS 04 (PTD 167-058) CBL Date:Tuesday, August 16, 2022 2:13:52 PM Attachments:image001.png image004.png Bryan, See below snapshots of the log below. I’m no CBL expert but I’m told by the guys around here that are - where the VDL gets lighter is roughly TOC for this vintage of log. Looks like ~8610’-8620’ is where that happens. The tubing tail where we will circulate cement from is listed as 8682’ ELM. So that would give us 60– 70 feet of overlap with the 9-5/8” casing annular cement assuming the LCM-plugged perforations don’t take any cement. Aras Worthington Hilcorp Alaska LLC Senior Technical Advisor for Alaska Operations Aras.worthington@hilcorp.com 907-564-4763 907-440-7692 mobile From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, August 16, 2022 12:47 PM To: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: [EXTERNAL] SMGS 04 (PTD 167-058) CBL Aras, Do you have the 9-5/8” casing CBL log? If the Cement top indicated on the wellbore diagram is correct, there might be a problem with your planned cement plug being above TOC in outside casing. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. 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Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, \ L.4,- —1 o S N -c) Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com AUG 0 b 2109 AIPAR Oil & Gas Cons, Commigfiion SC#IM OCT 0 3 2014 Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, I� Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 14-42 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase 1 Abandon abandon at end of platform life Br 18-42 1680120 Apr -89 Colla sed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platforrn life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 13-4 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 Fno known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug -9 parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for Tyonek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -91 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -0 no known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casing Producing Coal Phase I Abandon abandon at end of platform life Monopod A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of latform life v AL& SHA 011L AND GALS CONSERVATION COMUSSION June 22, 2009 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Dale Haines OCT 0 3 2014 UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubert@alaska.g.ov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 _ Union Oil Company of California 182-083 _ Trading Bay Unit D-40RD Union Oil Company of California 178-045 Trading Bay Unit G-08RD Union Oil Company of California 176-032 Trading Bay Unit G-24 _ Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 Trading Bay Unit G-34RD Union Oil Company of California 168-038 _ Trading Bay Unit K-06RD Union Oil Company of California 169-066 _ Trading Bay Unit K-09 _ Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 Trading Bay Unit K-23 Union Oil Company of California 165-038 _ MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS,St 17595 18 Union Oil Company of California 185-135 _ MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 _ S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 _ Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 _ Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 _ Union Oil Company of California 162-031 Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 Swanson Riv Unit 212-10 _ Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 _ Swanson Riv Unit 234-15 Union Oil Company of California 167-076 Trading Bay St A-10 _ Union Oil Company of California 172-020 Trading Bay St A-23DPN _ Union Oil Company of California 173-014 _ Trading Bay St A-30 ') ) ~~~~,E :} !Æ~!Æ~~«!Æ ATtASIiA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK/, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage,AK 99516-6247 ¿?}; If!li!l t~ftl Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confinns your conversation with COID...TIlission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approvaL., because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be llbmitted forthwith. ,~,. smcer~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this i!1ßay of November, 2004 SCANNED NOV 2 3 2004 Enel. ) STATE OF ALASKA ...., ALASKA OIL AND GAS CONSERVATION COMMIS;::JlÓN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: " .f. . Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal 1. Type of Request: 3. Address: P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 110' RKB 8. Property Designation: Dillon 11. Total Depth MD (ft): 10,550' Casing Structural Total Depth TVD (ft): 10,103' Length Conductor Surface 329' Intermediate Production 1,995' 10,515' Liner Perforation Depth MD (ft): Suspend U Repair well D Pull Tubing D I OCT 122004 Development Stratigraphic D D Service Exploratory D D 9. Well Name and Number: Di-04 10. Field/Pools(s): PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Size 20 13-3/8" 9-5/8" 8,820 to 9,315 Packers and SSSV Type: 8,471 t08,936 Perforation Depth TVD (ft): 10,467' Baker Model" D" Permanent P . With cemented PUP 12. Attachments: Detailed Operations Program 14. Estimated Date for Commencing Operations: D Description Summary of Propos 16. Verbal Approval: Commission Representative: Plugs (measured): Junk (measured): MD Burst Collapse TVD 329' 1,530' 2,734 psi 5,745 psi 520 psi 1,130 psi 3,087 psi 1,977' 10,070' Tubing Grade: Tubing MD (ft): LS: 3-1/2'" SS: 3-1/2" Packers and SSSV MD (ft): LS : 9420' SS : 68' Both 9.2#, N-80 9,360' 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D 0 Service D D D Abandoned WDSPL D D Plugged WINJ 17. I hereby certify that the foregoing is true a (j correct to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Printed Nam/)..me .. ~t. C. ~Ie ,- Signature Á4Í.t,ti// a~ Phone 28-Sep-2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,?C' 4- <131 Plug Integrity D BOP Test D Other: Subsequent Form Required: Approved by: -2. 4tJ,; . Form 10-4å'4"Revlsed 12/2003 Mechanical Integrity Test D Location Clearance D RBDMS BFL NOV 2 2 2004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION ORIGINA COMMISSIONER BY ORDER OF THE COMMISSION Date: Submit in Duplicate STATE OF ALASKA '1,-,,-' ."'~ ...«~ . .,~-..,...., ALASKA Oil AND GAS CONSERVATION COMMISSION tt~ t:-c L E ~ V ~~~, LJ REPORT OF SUNDRY WELL OPERATIONS FES 262004 1. Operations Abandon Performed: Alter Casing 0 Change Approved Program 0 2. Operator Union Oil of California Name: aka Unocal Suspend RepairWell D Pull Tubing 0 Operation Shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic D Perforate '. :' ~fi~r 0"\$ CmrW.H:\<ittwl Stimulate 0 AlitiJ\& Ë1He'rísióg ~hut in and secure . Jto.' !"j ''H Re-enter Suspended vvel' . , :;.. 5. Permit to Drill Number: Exploratory D 67-58 Service 0 6. API Number: 50-733-20047-00 9. Well Name and Number: Di-04 10. Field/Pool(s): Middle Ground Shoal/E & G 3. Address: P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): 110' RKB 8. Property Designation: Dillon 11. Present Well Condition Summary: Total Depth measured 10,550 feet true vertical 10,103 feet Effective Depth measured 10,467 feet true vertical 10,025 feet Casing Length Size MD Structural Conductor 1,995' 13-3/8" 1,995' Surface Intermediate Production 10,515' 9-5/8" 10,515' Liner Plugs (measured) Junk (measured) Fish @ 9,380, 10,162' 10,186 and 10,467' TVD Burst Collapse 1,977' 10,070' Perforation depth: Measured depth: 8,800-8,840 8,875-8,900' 9,125-9,180 9,200-9,225 9,425-9,430 9,440-9,480 9,550-9,605 9,685-9,695 9,720- 9,780 9,810-9,890 - --- .. ---- True Vertical depth: 8,451-8,4898,521-8,5458,757-8,809 8,828-8,852 9,041-9,046 9,055-,90939,159-9,211 9,287-9,2979,321- 9,377 9,406-9,481 - --- - -.- Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) LS: 2 7/8", 6.4#, L-80, Buttress @ 8,671' SS: 2 7/2", 6.4#, L-80, Buttress @ 8,661' Baker Model "D" Permanent Pkr. @ 9360' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: This well was shutin prior to and subsequent to operations 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Daily Report of Well Operations 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 0 GINJ 0 WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: Contact Printed Name P. M. Ayer Form 10-404 Revised 12/2003 \\S)CAJ~NE[" ~~A~ 1 @ 2004 Title Petroleum Engineer Signature UNOCALe Dillon Di-4 Rod Pump Completion Procedure Version #7 3/29/00 RKB to TBG Head = 34.15' GASING AND TUBING DETAIL Hn r. connection: 3-1/2" 8rd Top SIZE WT GRADE CONN ID TOP BTM. 20 Surf 329' 13-3/8" 61 K-55 12.515 Surf. 1995' 9-5/8" 40 & 43.5 N-80 8rd LT&C 8.755 Surf 10,515' Tubing: LS 2-7/8" 6.4 L-80 Butt. SC 2.441 8,671' SS 2-7/8" 6.4 L-80 Butt. SC 2.441 8,661' 5 JEWELRY DETAIL 6 NO. Depth ID HelD 34.15' CIW Dual Hanger I 8,671' 2.250" Kobe 2-1/2", "ALP" Dbl Parallel Cavity 2 8,691' 2.500" Crossover, 2-7/8" 8rd Box x 2-7/8" Buttress Pin 2 3 8,692' 2.441" I jt. 2-7/8", 6.4#, L-80, Buttress SC 3 4 8,724' 3.000" Mule Shoe, 2-7/8" Buttress Box E Short StrinQ 4 34.15' CIW Dual Hanger F 5 8,661' 1.995" Crossover, 2-7/8" Buttress Box x 2-3/8" 8rd Pin 6 8,663' 1.995" Pup, 2-3/8",4.6#, L-80, Buttress I I 9,360' 2.992" 9-5/8", 'BWD' Perm. Packer W/15' Cemented Pup PERFORATION DATA Zone Top Btm Amt SPF Perf Date Pro posed E 8,800' 8,840' 40' 4 êlJi1-/q 1; New E 8,875' 8,900'. 25' 4 ;)/9:/9<3 New F 9,125' 9,180' 55' 4 iJ-IO IQß New F 9,200' 9,225' 25' 4 ¡;z/~Jq'ð New F 9,290' 9,315 25' 4 ;;1.JrÃ)9'ð New G-1 9,425' 9,430' 5' 4 12/20/67 ' Suspended 9,440' 9,480' 40' 4 4/26/69 . Suspended G-2 9,550' 9,605' 55' Cmt Sqz'd G-3 9,685' 9,695' 10' Cmt Sqz'd PBTD = 10,467' G-3 9,720' 9,780' 60' 10,8 & 4 1/7/81 ' Suspended HOLE ANGLE thru Interval = 18~ 9,810' 9,890' 80' 12, 8 & 4 1/7/81 ' Suspended G~4 9,920' 10,070' 150' 12,10,8&6 . Suspended Rod Pump Install Ver 7 3-29-00.doc 14 OS/27/00 Fill Tagged w/ 2.35" GR 3/31/95 @ 10,039' WLM FISH: Baker Model "0" Production Pkr 9,380' 30' of Through tbg gun 4spf 12/20/67 10,467' MO 20' Perf gun wI Collar locator 4/25/67 10,467' MD Guiberson type "A" Wireline pkr. 9/02/75 10,186' MD Drld Bridge Plug 12/17/80 10,162' MD STIMULA TIONS: 4/6/77 Corco Chemical Surfactant Water Shut-of! DILLON PLATFORM API # 50-733-20047-00 S. MGS UNIT # 4 WELL HISTORY Well #4 DATE COMPLETED 1968 1/4 EVENT Completed as an Oil Well. 1997 11/30 WL - RIH WITH 2" GO FISHING SOCKET BAITED WITH 2 V2" JDC TO 9312' BLM. LATCH FISH JAR LOOSE. POOH WITH STANDING VALVE. LAY DOWN E LINE TOOL STRING. RIH WITH STANDING VALVE PULLING TOOL TO 9,332' BLM. LATCHED STANDING VALVE. JARRED TWICE. SLIPPED OFF. WILL NOT RELATCH, POOH RIH WITH LONG EQUALIZING PRONG TO 9,332' BLM. JAR DOWN. POOH. RIH WITH 2.75" LIB. FOUND FLUID LEVEL AT 500' BLM. POOH. 12/1 WL - REMOVE LUBRICATOR AND RISER. PUT ON CAP AND TRY TO PUMP THROUGH STANDING VALVE. PRESSURE UP WELL TO 3,000 PSI. HOLD LB. LEAVE 2,500 PSI ON WELL FOR NIGHT 1998 1/13 Hydraulic Workover, Abandon HK, recomplete Tyonek 6/30 WL - (LS) RIH wI EQ Prong to 8,671' KB, jarred down, well on vacuum, POOH. RIH wI Standing Valve Pulling tool to 8,671' KB, latched Standing Valve, POOH. RIH wI 2.0" Gauge Ring to 9,360' KB, tagged Packer, POOH, Tbg clear. RIH wI Standing valve on shake off tool to fluid (1,750'), shake off standing Valve. WL - (LS) RIH wI Knock out tool to 8,671' KB, jarred down, well on vacuum, POOH. RIH wI Standing valve pulling tool to 8,671' KB, latched standing valve, POOH. RIH wI new standing valve assembly to fluid @ 2,500', shake off, POOH. 7/15 7/24 TAG -(LS) (Pulled Standing Valve, ran scratchier, tagged fill.) RIH wI EQ Prong to 8,671' KB, jarred down, well on vacuum, POOH. RIH wI S.V. Pulling tool to 8,671' latched S.V., POOH. Some paraffin on seal. RIH wI B-line brush to 9.360' KB, taaaed fill. pulled up to 8,600', worked back & forth from 8,600' to 8,800', POOH. RIH wI S.V. to 8,400' shake off, POOH. 7/28 WL - (SS) (Set w-Plug, pressured up tubing, pulled plug.) RIH wI 2 7/8" W-Plug on JDC pulling tool wI 2.25" gauge ring on bottom to 8,661' KB, jarred down for 20 min, POOH, still had plug, ran back to 8,661' KB, jarred down for 15 min, POOH, Still had plug, tool sheared, didn't release. RIH w/2 7/8" W-Plug on SB pulling tool wI 2.25" Gauge ring on Di-4 Hist 7-29-99.doc, last revised 2/23/2004 page 1 9/10 9/16 9/17-19 1999 1/13 4/6-1 0 6/12 7/28-29 bottom to 8,661' KB, set down. Started pressuring up, won't pressure up. Jarred down 3 times, started building up pressure to 1,000#, held for 20 min, POOH wI Plug. RIH wI 2 Y2 Kobe standing valve pulling tool wI well flowing to 8,671' KB, latched & pulled SV WI gauges. Retrieved data from gauges. Rigged down, PS - (Set BHP instruments on bottom of Kobe standing valve @ 8,716' KB.) Engaged batteries on Top BHP instruments. Engaged batteries on Bottom BHP instruments. Open swab valve. RIH wI BHP instruments on bottom standing valve to 8716' KB. On bottom wI BHP instruments (8716). WL - Installed swab cups & began swabbing runs. Found fluid @ surface , see swabbing report for details. Fluid level @ 1 ,275' total barrel @ end of. 1 st 24 hr period 53.1 barrels. Casing fluid level @ 1100' Tubing pressure 20# Continued swabbing tubing. Start day wI fluid level @ 1275' & meter total of 54.0, see swabbing report for details. Changed out swab cups. Fluid level @ 1680'. Tubing meter reading 94.9 Barrels recorded. (Swabbing tubing.) Fluid level @ 1,700', meter reading 94.9, continued swabbing tubing. Started getting paraffin in swab cups, causing cups to stick in tubing & rolling edges of cups. Tools stuck @ 564', had to jar @ 2,500# to free up, finally pulled out of hole. Found cups rolled & packed wI paraffin. discussed options wI Foreman. Rigged down & secured well. Last fluid level was 1,925 & total barrels recovered 119.3 barrels of water. Rod pump completion (SWR, lease costs for pumping unit) TAG - WL - Pulled standing valve, run gauge ring, tried to clean scale from tail pipe. RIH wI 2.0" pump bailer to 9,532' KB, worked bailer 20 min., POOH wI bailer bottom full of scale. Got sample of scale for analysis. Bailed from 9,532' to 9,540' KB. Bailed sand & scale from 9,521' to ,9525' KB. Removed Y2 of 5 gallon bucket of sand from well. NOTE: Measurements were incorrect on previous WSR's, these are accurate measurements. RIH wI 1.75" DD bailer to 9,545' KB, worked to 9,547' KB, fell through, taaaed fill @ 9.940' KB, Clean tubing out to 2.255", drop standing valve. Pump sealant downhole to repair pump cavity leak. 0 - (Tension Joint Leak Repair) Mixed and Pumped Seal-Tite pill. Pressure on the SS increased to 900 psi for 1 min @ 40 bbls displacement indicating sealant going through the tension joint. SS pressured up, Switched to LS and pumped the following treatment: LS on vacuum. Di-4 Hist 7-29-99.doc, last revised 2/23/2004 page 2 9/16 2000 7/25 2002 12/07/2002 70 Gals WA 50:1 35 Gals Flo-Seal I 35 Gals Flo-Seal II 20 Gals Gly-Flo 20 Gals WA 50:1 Seal-Tite pumped away. Found pump in well. Pulled pump from well. Rod pump completion (capital recompletion to install lift equipment). Perf Tyonek E & F sands This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. Di-4 Hist 7-29-99.doc, last revised 2/23/2004 page 3 Don Sta dual LEG ROOM Itl WElL " 2D"x 13 3/88 133/8" x 9 5/88 9 5/8" x 3 1/2!' 1 bbIs 28 bbIs 22 bbIs 4 bbIs 15.5bb1s 30 bbIs ~ ABN-IO 01.13 LEG ROOM #2 E 01.18 20bbJs 01.17 15.5ÞbIs 20 bbl. 01-16 15 bbIs 20bbJs 01-11 5 bbIs 7;4bbIs 01-8 2 bÞJs 25 bbIs 01-7 ABN-6 ~ LEG ROOM #4 0'.5 -:: rbbls ~ 01.3 12 bbIs 25 bbls 20 x 13 518 0.1815 300 54.45 31/2 tbg. 0.0087 300 2.61 18 518 x 13 318 0.1291 300 38.73 2 7/8 tbg. 0.00579 300 1.737 13 318 x 9 5/8 . 0.0671 300 20.13 C. 858 334 9 5/8 x dual 3 1/2 0.0507 300 15.21 355 9 518 x dual 2 7/8 0.0571 300 17.13 pump limit 21 psi 9 5/8 x 3 1/2 0.0626 300 18.78 we" .2 wen M we" #9 We" # 10 We" "13 We.. "7 We.. tIS We" "11 we" "16 We.. 17 We"" 18 well 83 We" "5 We"" 12 We" #14 we" #15 WELL BAY # 1 Pumped down tbg.tbg on vac, bled down 9 5/8 x tbg. Pumped 28 bbls. Gas still at surface. Pumped down 20x 135/8 2bbIs 100 psi. 20 bbls in 13 3/8. Try to pull eclipse paker with wire line could not get out. Well had 180 on annulus and 150 on tbg would not bleed down, Tryied pumping down short side old pump in hole could not pump. Put 30 bbls of 9.8 in annulur 9 5/8x tbg. Pumped down l.s. tbg. Retumed up short side 100 bbls. Put 15 bbls In 13 5/8x9 5/8. 4 bbls In 20" ann. Hook up to 20" took approx 1 bbI with charge press on ann. 13 3.8J: ~ 5/8 Rump and bleed 3 ~ i~ an~. 9 5/8xtbg fluid packed with oil. 14.4 bblsin tbg. well 10 is abondoned FiII20n ann 2 bbls. tbg on vac 7bbls in 13318 x 9 5/8 28 bbls 9 5/8 x tbg. 51.5. 5 s.s.bbls down short side did tbg. And ann same time WELL BAY # 2 20n fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Have oil returns 0 press on well. 20" fluid packed, 13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped Sbbls In tbg.' 20 bbIs in 9 5/8 ann.Annulus and tbg. Press up to 500 psi. on both tbg. Strings had on to top no press on tbg. Pumped and bled 7bbls in tbg. Annulus. When annulus was fluid packed. Oil at surface.5 bbls in 13 5/8 x 9 5/8 press limit . ~5 bbls in 20" Well had SOpsi. On 13 3/8x 9 5/8 bleed down to 20psi put bbls of 9.8 fluid. 95/8onn. 20 bbls fluid, tbg.5bbls each, wells 185/8 has 110 psi. bled off and fluid packed with press limit of 50 psi..75 of a bbl. Well had loopsl. On 13 3/8x 9 5/8 bleed down to 20psi put ISbbIs of 9.8 fluid, 95/8ann. 20 bbls fluid, tbg.5bbls each. wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had 150psi. On 13 3/8x 9518 bleed down to 20psi put 20bbls of 9.8 fluid. 95/8onn. 20 bbls fluid, tbg.5bbls each. wells 185/8 has25 psi bled off and fluid packed with 9.8 salt took 1.2 bbls. WELL BAY # 4 Rig up pump 4 bbls 1.5. 4 bbl s.s. 9 5/8 x tbg. 25 bbls, 13 3/8 x 9 5/8 fluid packed w 112 bbls. 20" ann. 2 bbIs. Auid packed Pumped 4 bbls 1.5. tbg. 4 bblss.s.R/u to 9 5/8 x 3 112 ann. Pumped 15 bbls fluid packed oil to surface. Pumped 4bbls down tbg Is, 4 bbIs 5.5. both went on vac. Pumped 15 bbls 95/8 x31/2. WIth50 psi press limit 0 bbls in 13 3/8x 95/8 Fluid packed 20x 133/8 2 bbls, Auld packed 13 3/8x9 5/8 12 bbIs press up to 200 psi and held. Rig up pump 5 bbls 1.5. 25 bbl s.s. Be 9 5/8 x tbg. 8 bbls fluid packed 011 to swface 13 5/8x9 5/8, RIU to 20" ann fluid pack 5 bbls. Press limit 20 psi. · Unocal Corporation P.O. Box 196247 ~ Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager 12/13/OO ' Alaska.Oil & Gas Conservation Commissio~n 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Middle Ground Shoal Well Di-4 APl No. 50-733-20047-00 10-404 Perforate E-Zone Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the E zone in well Di-4. The following intervals were perforated on 8/8/00: Bench Top Bottom Feet R £ C E I V E D E 9,130 9,160 30 Total: 50 J,~N 2 ~ ~001 If you have any questions, please contact RalPh Holman at 263-7838.41aska Oil & (;as Cons. Commission Anchorage Sincerely, Dan Williamson Drilling Manager ?-'"' STATE Of ALASKA ,. ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 110' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: ,,~ Middle Ground Shoal P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 748' FSL, 1820' FWL, Sec. 35, T8N, R13W, SM 4 At top of productive interval 9. Permit number/approval number 2134' FNL, 1955' FWL, Sec. 35, T8N, R13W, SM 67-058 At effective depth 10. APl number 1791' FNL, 2112' FWL, Sec. 35, T8N, R13W, SM 50-733-20047-00 At total depth 11. Field/Pool 1791' FNL, 2112' FWL, Sec. 35, T8N, R13W, SM Middle Ground Shoal/E & G 12. Present well condition summary Total depth: measured 10550 feet Plugs (measured) true vertical 10103 feet Effective depth: measured 10467 feet Junk (measured) true vertical 10025 feet Casing Length Size Cemented Measured depth True vertical depth Structural 329' 20" Ddven 329' 329' Conductor 1995' 13-3/8" 625 sx 1995' 1977' Surface Intermediate Production 10515' 9-5/8" 1450 sx 10515' 10070' Liner Perforation depth: measured 8820-8840, 9130-9160, 9425-9430, 9440-9480, 9550-9605, 9685-9695, 9720-9780, 9810-9890, 9920-10070 true vertical 8471-8489, 8762-8791,9041-9046, 9055-9093, 9159-9211, 9287-9297, 9321-9377, 9406-9481, 9509-9649 Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, N-80, Buttress @ 9420' SS: 3-1/2', 9.2#, N-80, Buttress @ 68' Packers and SSSV (type and measured depth) Baker Model "D" Permanent Pkr. @ 9380' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data OiI-BBL ' Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 70 90 80 Subsequent to operation 0 0 0 90 80 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~ ~~//~ ' Title: ~/VI' I" ~~ ~h~ Date: / "~~ ~"'(~/ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLIC~ '~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Development: X KB 110' above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: ~,,~, Middle Fround Shoal Anchorage, AK 99519-6247 Service: Dillon Platform 4. Local~on of well at surface 8. Well number 748' FSL, 1820' FWL, Sec. 35, T8N, R13W, SM Di-4 At top of productive interval 9. Permit number/approval number 2134' FNL, 1955' FWL, Sec. 35, T8N, R13W, SM 67-058/300-03 At effective depth 10. APl number 50-733-20047-00 At total depth 11. Field/Pool 1791' FNL, 2112' FWL, Sec. 35, T8N, R13W, SM Middle Ground Shoals/E, F & G Pool 12. Present well condition summary Total depth: measured 10550 feet Plugs (measured) true vertical 10103 feetORI61NAL Effective depth: measured 10467 feet Junk (measured) true vertical 10025 feet Casing Length Size Cemented Measured depth True vertical depth Structural 329' 20" Driven 329' 329' Conductor 1995' 13-3/8" 625 cuff 1995' 1977' Surface Intermediate Production 10515' 9-5/8" 1450 sx 10515' 10070' Liner Perforation depth: measured 9425'-9430', 9440'-9480', 9550'-9605', 9685'-9695', 9720'-9780', 9810'-9890', 9920'-10070' true vertical 9041 '-9046', 9055'-9093', 9159'-9211 ', 9287'-9297', 9321'-9377', 9406'-948 1', 9509'-9649' Tubing (size, grade, and measured depth) LS = 3-1/2" ,9.2 #/ft, N-80, Butt @ 8671', SS= 3-1/2", 9.2 #/ft, N-80, Butt @ 8661' Packers and SSSV (type and measured depth)~,,,;,, r%,?"" ~""'" ~ ~"5#; 5!;~'~;.,.,, ~rt.,,,,. Baker Model D Perm Packer @9380' 13. Stimulation or cement squeeze summary "~"' 0 2 2'000 Intervals treated (measured) AiaAa 0it & Gas C~q~,. Commission Treatment description including volumes used and final pressure /~J~O[~8 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 Subsequent to operation 0 70 0 100 rod pump 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Title: Drilling Manager Date: ,.'3 ~ll ~ Form 10-404 Rev 06/15/88 AFE #135612 SUBMIT IN DUPLICATE UNOCAL Alaska Drilling Drilling Summary Report Di-4 4/6/00 to 4/10/00 3/24/00 4/6/00 4/7/00 4/8/00 4/9-10/00 RU APRS on short string. Punch tubing holes at 8652'-8658'. NU BOPs on top of Di-4 short string, test same. RU riser and circulating lines to tree. RU rod running equipment with crane. Run 2-1/2" rod pump and %" x 7/8" x 1" tapered rod string with rod guides to 8620'. PU to set anchor at 8620'. Space out and install polish rod. RU flowline and hydraulic pump line. Begin pumping well at 21:30 hrs on 4/10/00. UNOCAL Dillon Di-4 Rod Pump Completion Procedure Version g7 3/29/00 RKB to TBG Head = 34.15' 3-1/2" 8rd 2000 I 1 1 G2 G3 : ~4 PBTD = 10,467' HOLE ANGLE thru Interval = 18.°5 =ASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 20 13-3/8" 61 K-55 9-5/8" 40 & 43.5 N-80 Tubing: LS 2-7/8" 6.4 L-80 SS 2-7/8" 6.4 L-80 12.515 8rd LT&C 8.755 Butt. SC 2.441 Butt. SC 2.441 Surf Surf. Surf 329' 1995' 10,515' 8,671' 8,661' NO. Depth ID JEWELRY DETAIL Item 34.15' 1 8,671' 2.250" 2 8,691' 2.500" 3 8,692' 2.441" 4 8,724' 3.000" 34.15' 5 8,661' 1.995" 6 8,663' 1.995" I 9,360' 2.992" CIW Dual Hanger Kobe 2-1/2", "ALP" Dbl Parallel Cavity Crossover, 2-7/8" 8rd Box x 2-7/8" Buttress Pin 1 it. 2-7/8", 6.4~, L-80, Buttress SC Mule Shoe, 2-7/8" Buttress Box Short String CIW Dual Hanger Crossover, 2-7/8" Buttress Box x 2-3/8" 8rd Pin Pup, 2-3/8", 4.6g, L-80, Buttress 9-5/8", 'BWD' Perm. Packer W/15' Cemented Pup Fill Tagged w/2.35" GR FISH: Baker Model "D" Production Pkr 30' of Through tbg gun 4spf 20' Perf gun w/Collar locator Guiberson type "A" Wireline pkr. Drld Bridge Plug STIMULATIONS: 3/31/95 @ 10,039' WLM 9,380' 12/20/67 10,467' MD 4/25/67 10,467' MD 9/02/75 10,186' MD 12/17/80 10,162' MD 4/6/77 Corco Chemical Surfactant Water Shut-off Zone Top E 8,800' E 8,875' F 9,125' F 9,200' F 9,290' G-1 9,425' 9,440' G-2 9,550' G-3 9,685' G-3 9,720' 9,810' G-4 9,920'- PERFORATION DATA Btm Amt SPF Perf Date 8,840' 40' 8,900' 25' 9,180' 55' 9,225' 25' 9,315 25' 9,430' 5' 9,480' 40' 9,605' 55' 9,695' 10' 9,780' 60' 9,890' 80' 10,070' 150' Proposed 4 New 4 New 4 New 4 New 4 New 4 12/20/67 ' Suspended 4 4/26/69 · Suspended Cmt Sqz'd Cmt Sqz'd 10,8&4 1/7/81 -Suspended 12, 8 & 4 1/7/81 Suspended 12, 10, 8 & 6 · Suspended Rod Pump Install Vet 7 3-29-00.doc 14 05/27/00 UNOCAL Dillon Di-4 Rod Pump Completion Procedure Version #7 3/29/00 Dillon 4 Rod PUmD Completion Tapered Rod String w/8 Huber 7" long x 2.25" OD stealth XL rod guides per rod 139 of 1" x 25' T66 Rods w/class T Couplings. 139 of 7/8" x 25' T66 Rods w/class T Couplings. 141 of 3/4" x 25' T66 Rods w/class T Couplings. 3 of 1-1/2" x 25' Weight Bar w/class T Couplings. 2-7/8" Short String 2-7/8" Long String Trico RXBC 2-1/2" x 2" x 26' Insert Rod Pump w/CPID barrel, 60 Ring Actuated plunger, Tungsten carbide seats, Titanium carbide balls, insert guided valve cages, spiral rod guide, %" x 1" crossover and 1" x 2' T66 Ponv rod. 6' of tbg punched holes @ 8652'-8658' 2-7/8" Oil Master Insert Pump Anchor w/24" stroke w/12" strainer Nipple. 2.290" OD Damaged Cavity @ 8,671' 2.25 ID 2O00 Rod Pump Install Ver 7 3-29-00.doc 15 05/27/00 STATE OF ALASKA ALASKA elL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 110' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Middle Ground Shoal 4. Location of well at surface v,,Dillon P~latf~j;~, Leg # 1, SI°t # 2 8. Well number 748' FSL, 1,820' FWL, Sec. 35, T8N, R13W, SM #4 At top of productive interval 9. Permit nu~,j~r 2,134' FNL, 1,955' FWL, Sec. 35, T8N, R13W, SM 67-058 '" At effective depth 10. APl number. 50- 733-20047-00 At total depth 11. Field/Pool 1,791' FNL, 2,112' FWL, Sec. 35, T8N, R13W, SM Middle G rour'~l~SlN;~aJ~ ",~,", 12. Present well condition summary K ~ L Total depth: measured 10,550' v" feet Plugs (measured) true vertical 10,103' feet J/~J~.l ~7 ~000 Effective depth: measured 10,467' feet Junk (measured) true vertical 10,025' feet AJa~ Oil & Gas Cons. Commission Anchorage Casing Length Size Cemented Measu red depth True vertical depth Structural 329 20" Driven 329' 329' Conductor 1,995' 13-3/8" 625 sx 1,995' 1,977' Surface Intermediate Production 10,515' 9-5/8" 1450 sx 10,515' 10,070' Liner Perforation depth: measured 9425'-9430', 9440-9480', 9550-9605', 9685-9695', 9720-9780', 9810-9890', 9920-10,070' true vertical 9041'-9046', 9055-9093', 9159-9211', 928779297', 9321-9377', 9406-9481 ', 9509-9,649' Tubing (size, grade, and measured depth) ss:LS: 3'1/2" 9'2#' N'80' Butt @ 9'420'3-112", 9.2#, N-80, Butt @ 68' Packers and SSSV (type and measured depth) Baker Mod 'D' Perm Pkr @ 9,380' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: Wellbore Diagram 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I horob~e~'~hat th~for~o~i~.m~ ~; c/~rrec, to the best of my knowledge.. .. Signed:~~..~ Title: ~,~0 ~. ~ Date:- ' FOR COMMISSION U~ ONLY ~/ Conditions of approval: Notify Commission so representative may witnessJ' I--~lAppr°va~l N~o.~_O{~_:~ Plug integdty~ BOP Test.~ Location clearance.~ Mechanical Integrity Test Subsequent form required 10- · ORIGINAL SIGNED' BY Robert N. Chdstenson Approved by order of the Commissioner Commissioner Date / "' 2 "~-" ~--~_-~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment Unocal request a variance to APl RP 14B "No Flow" test on Dillon #4. The current Shut-In surface pressure is 270 psi. The well will flow 8.75 gallons per hour. It is Unocal's intention to run a red pump completion in this well. The rod pump completion will be capable of lifting 350 BPD production. There is no pressure support in this interval and Unocal anticipates, through time, the depletion of the E & F sands. RECEIVED dAN 07 2000 Anchorage 8 10 11 Dillon 4 Rod Pump Installation Procedure RU slickline unit. Run 2.35" gauge ring in shod string to 8661'. Run braided line brush to clean out tubing from 8661' to 8600'. RU E-line and punch holes in shod string tubing at 8655'-8661' with 4 spf. RU two variable ram BOPs with pump-in sub on short string. Pressure test against closed master valve to 1500 psi and 300 psi. RU pump and water source line to shod string side for contingent kill operations. Circulate shod string tubing volume to inlet water. Monitor well for flow. If slight flow still exists, have lines open from pump in sub and from tubing x 9-5/8" annulus to skimmer tank. Run rod pump with anchor on 3,~" x 7/8" x 1" tapered rod string with crane. Position pump anchor within 10' of tubing punched holes. Set anchor by picking up full pump stroke length of 22' plus 2' and setting down. Install Rod Hanger device. Install hydraulic rod pumping unit and polish rod to rod string. Install flowline. Begin pumping well and injecting paraffin inhibitor down annulus. RECEIVED j'A 2000 UNOCAL$ Dillon Di-4 Rod Pump Completion Procedure Version #4 11/12/99 Dillon Di-4 BOP Arran.qment While ruflllJl~q Rods Rod Elevator plate ~/Rod wiper Bowl. Deck 2.43' 7.13' 4.7' Rod Pump Install Vet 4 11-12-99.doc 16 Pollard 3-1/2"~ 9,~#~ N-80 Riser pup joint w/ Bowen 2-1/2"Qtfi'~ connect union top & btm. Pollard 3-1/2' Pt~--in sub w/Bowen 2- 1/2''Quick Cott'n~.t Union. Weathered Type LP Blowout Preventer 1500 psi ~ Variabl~ 0 tO 1-1/2" Ram 2.44" iD w/Bov/~t~ 2-l/2"Quick Connect Unions top & btm ,, Flange 2-1/16" SM X Bowen 2-1/2" Quick Union RECEIVED JA~ ~,? ~000 12/17/99 UNOCALe Dillon Di-4 Rod Pump Completion Procedure Version #4 11/12/99 Dillon Di-4 site-Plan While Runnin~q Rods Drill Deck 7.13' 2.43' Return Line to Skimmer Tank Kill Line RECEIVED' jAN G? 2000 Return Line to//4 l~oduct/on Tank Return Line to Skimmer Tank Rod Pump Install Vex 4 11-12-99.doc 19 12/17/99 UNOCAL ) Dillon Di-4 Rod Pump Completion Procedure Version 12/29/99 RKB to TBG Head = 34.15' Hn, 3-1/2" 8rd REC :iVED ?- 000 PBTD = 10,467' HOLE ANGLE thru Interval = 18:S 4 ' --Gl _~G1 =G2 =G3 _- E .=G4 :ASING AND TUBING DETAIL SiZE WT ,.GRADE CONN ID TOP BTM. 20 13-3/8" 61 9-5/8" 40 & 43.5 Tubing: LS 2-7/8" 6.4 L~O SS 2-7/8" 6.4 I.~80 12.515 8rd LT&C 8.755 But~ SC 2.441 Butt. SC 2.441 Surf 329' Surf. 1995' Surf 10,515' 8,671' 8,661' NO. Depth ID -34.15' 1 8,671' 2.250" 2 8,691' 2.500" 3 8,692' 2.441" 4 8,724' 3.000" 34.15' . 5 8,661' 1.995" 6 8,663' 1.995" I 9,360' 2.992" JEWELRY DETAIL CIW ~al Hanger g~t~ ~'q/2", "ALP*' ~1P~el ~ty ~9~, 2-7~" 8rd Box x ~7~" Bu~ ~n 1 jt 2-7~,,, 6.~, L-80, Bum~ SC Mule ~, ~7~" Bum~ Box ~Strinfl ~Vg, 2-7~" Bu~ Box x ~3/8" 8rd ~n ~, ~,3n,,, 4.~, L-So, s~ 9,~i8"'~ 'BWD' Perm. Packer WI 15' Cemented Pup Fill Tagged wi 2.35" GR FISH: Baker Model "D" Production Pkt 20' Perf gun w/Collar locater Ouiberson type "A" Wireline p~. Drld Bridge Plug STIMULATIONS: 3/31195 @ 10,039' WLM 9,380' 12/20/67 10,467' MD 4/25167 10,467' MD 9/02/75 10,186' MD 12117/80 10,162' MD 416/77 Corco Chemical Surfactant Water Shut-off Zone Top PERORATION DATA B tm .......... ,Am t 8 P g Perf Date E 8,800' 8,840' 40' E 8,875' 8,900' :~5' F 9,125' 9,180' ~5' F 9,200' 9,225' ~.5' F g,2g0' 9,315 ~5' G-1 9,425' 9,430' ~' 9,440' 9,480' 40' G-2 9,550' 9,605' ~5' G-3 9,685' 9,695' 10' G-3 9,720' 9,780' G0' 9,810' 9,890' GO' G-4 9,920' 10,070'r .......t~0' 10,8 & 4 12,8&4 12, 10,8&6 12/20~67 4/26/69 1/7/81 1/7/81 Propoeod New New New New New Suspended Suspended Cmt Sqz'd Cmt Sqz'd Suspended Suspended Suspended Rod Pump Install Vet 5 12-29-99.doc 14 12/29/99 UNOCAL Dillon ,4, Prono-qed ROd Pumr) Comr)letlofl Dillon Di-4 Rod Pump .Completion Procedure Version #5 Tapered Rod String w/8 Huber 7~' long x 2.25" OD stealth XL rod guides per rod 139 of 1" x 25' T66 Rode w/.01ass T Couplings. 139 of 7/8" x 25' T66 Rode w/class T Couplings. 141 of 3/4" x 25' T66 Rode w/class T Couplings. 3 of 1-1/2" x 25' Weight Bat'' w/class T Couplings. 2-7/8" Short String 2-7/8" Long String Trico RXBC 2-1/2" x 2" x 26' Insert ROd Pump w/CPID barrel, 60 Ring Actuated plunger, Tungsten carbide ~ts, Titanium carbide balls, insert guided valve cages, spiral rod guide, ~" x 1" crossover and 1" x 9' T66 Pony rod. 6' of tbg punched holes 2-7/8" Oil Master Insert Pmnp Anchor w/24" stroke w/12" strainer Nipple. 2.290" OD Damaged Cavity @ 8,671' 2.25 ID RECEIVED jA~I ~7 2000 Rod Pump Install Ver 5 12-29-99.doc 15 12/29/99 STATE OF ALASKA ALASKA O"iL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: X Pull tubing: Variance: Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (Unocal) Development: X 110' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: ~,~ Middle Ground Shoal 4. Location of well at surface Dillon Platform, Leg # 1, Slot # 2 8. Well number 748' FSL, 1,820' FWL, Sec. 35, TSN, R13W, SM #4 At top of productive interval 9. Permit number 2,134' FNL, 1,955' FWL, Sec. 35, TSN, R13W, SM 67-058 At effective depth 10. APl number 50- 733-20047-00 At total depth 11. Field/Pool 1,791' FNL, 2,112' FWL, Sec. 35, T8N, R13W, SM Middle Ground S~aj4 "~:~' r' 12. Present well condition summary J~ r' ~ [,,, Total depth: measured 10,550' feet Plugs (measured) true vertical 10,103' feet J~,[~ 2 ~ 1998 Effective depth: measured 10,467' feet Junk (measured) true vertical 10,025' feet Alaska 0il & Gas Cons. CommiSSiOn Anchorage Casing Length Size Cemented Measured depth True vertical depth Structural 329' 20" Driven 329' 329' Conductor 1,995' 13-3/8" 625 sx 1,995' 1,977' Surface Intermediate Production 10,515' 9-5~8" 1450 sx 10,515' 10,070' Liner Perforation depth: measured 9425'-9430', 9440-9480', 9550-9605', 9685-9695', 9720-9780', 9810-9890', 9920-10,070' true vertical 9041 '-9046', 9055-9093', 9159-9211 ', 9287-9297', 9321-9377', 9406-9481 ', 9509-9,649' Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, N-80, Butt @ 9,420' ss: ORIGINAL Packers and SSSV (type and measured depth) Baker Mod "D" Perm Pkr @ 9,380' 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: X 14. Estimated date for commencing operation 15. Status of well classification as: 1/12/1998 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ Title: Drilling Manager Date: 1/20/98 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval ,N,o... Plug integrity ~./' BOP Test V'~ Location clearance~ J ,..,,'~ Mechanical Integrity Test Subsequent form required 10- ..~o~.e.~,~,.~,. Original Signecl u) t,~¥~,e-.,~~ David W. Johnston Approved by order of the,~l"nmis"sioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IIq 3ATE ~--.~ UnocalCorporation P.O. Box 196247 Anchomge, Alaska 99519 907-263-7660 UNOCAL ) Dan Williamson Drilling Superintendent Wednesday, January 21, 1998 RECEIVED Naska 0il & Gas Cons. Commission Anchorage Mr. Blair Wondzell Alaska O&G Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1392 Dear Mr. Wondzell, In regards to our telephone conversation on January 13, 1998, new information has been presented by our Reservoir Department that has altered the scope of the Dillon 4 well work. The perforation intervals have been expanded and now also include 9,290-9,315 M.D. The Reservoir Department feels that this interval could be the most productive. However, this would place our previously proposed Bridge Plug setting depth of 9,326' M.D., only 16 feet below the lower most perforation leaving a minimal amount of rat hole. With this consideration we have revised our procedure to include attempting to pull the entire tubing string to allow for a maximum Bridge Plug setting depth of 9,375' (immediately above the packer) in order to allow for the maximum amount of rat hole. Enclosed is a revised application for Sundry Approval (Form 10-403) respectfully requesting a change of an approved program in which the setting of the Bridge Plug be allowed for isolation of the Hemlock and to reflect the expanded perforation intervals. It is our concern that spotting a 50' plug on top of the bridge plug will leave a minimum amount of rat hole and may necessitate a clean out run. Due to the economic sensitivity of this work and the substantial cost of tripping with the Hydraulic Workover Unit, having to perform this work would be a considerable burden to the economics of the project. The timing to begin the work is approximately January 26, 1998. If you should have any questions regarding this request please contact me at 263-7677. Thank you for your attention to this matter. Sincerely, Dan Williamson Drilling Superintendent Middle Ground Shoal Well # D-4 Completed 2/17/83 RKB to TBG Head = 34.15' Tree connection: ?? 5 6 7 _= G1 --=----Gl --. G2 G3 G3 .. -- G3 -- -- -- G4 9qa~' PBTD = t0,467' TD = 10,550' HOLE ANGLE thru Interval = t8.o5 D-4Draw.doc SIZE CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. LS SS 20 13-3/8" 61 K-55 12.515 9-5/8" 40 & 43.5 N-80 8rd LT&C 8.755 Tubing: 3-1/2" 9.2 N-80 Butt. 2.992 3-1/2" 9.2 N-80 Butt. 2.992 Surf 329' Surf. 1995' Surf 10,515' 0' 9430' 0' 68' JEWELRY DETAIL NO. Depth ID Item 34.15 1 9326' 2 9351' 3 9377' 4 9386' 5 9380' 6 9387' 7 9430' 2.687 4.00 CIW Dual Hanger 3.5 EZ Drill (With one way check valve) Kobe 3 E Pump SN 2344. w/six 1" diameter holes, 24.74' long 8.47' Blast Joint Locator Seal Assy. w/12.65' of seals Baker Model "D" Retainer Production Pkr. Magna Range Bridge Plug Baker Mule shoe Fill Tagged w/2.35" GR FISH: 30' of Through tbg gun 4spf 20' Perf gun w/Collar locator Guiberson type "A" Wireline pkr. Drld Bridge Plug 3/31/95 ~ 10,039' WLM 12/20/67 ~ 10,467' MD 4/25/67 ~ 10,467' MD 9/02/75 ~ 10,186' MD 12/17/80 ~ 10,162' MD STIMULATIONS Corco Chemical Surfactant Water Shut-off treatment r 4/6/77 PERFORATION DATA Accum Last Zone Top Btm G-I 9,4251 9,430' 9,440' 9,480' G-2 9,550' 9,605' G-3 9,685' 9,695' G-3 9,720' 9,780' 9,810' 9,890' G-4 9,920' 10,070' Amt SPF 5 4 40 4 55 10 6O 8O 150 10,8& 4 12,8&4 12, 10,8&6 Perf Date Present Condition 12/20/67 Open f/Prod 4/26/69 Open f/Prod Cmt Sqz'd Cmt Sqz'd 1/7/81 Open f/Prod 1/7/81 Open f/Prod Open f/Prod DATED: 5/23/97 ASSEMBLED BY STEVE TYLER UNOCALe -" '~'K'B-to 'I'BG Head - 34.15' Tree (:onnection: ?? 5 .--= F I 'x,_._. 4 __ 11o3 -- =_(3 SIZ~ Dillon Well No. 4 Proposed Completion CASING AND TUBING DETAIL WT GRADE CONN ID TOP BTM. K-$5 12.515 N-S0 8rd LT&C 8.755 I.,-80 Bull SC 2.44L L-gO Butt. $C 2.441 JEWELRY DETAII, Item Surf 329' 5afl, 1995' Surf 10,515' SS 20 13-3/8" 61 9-$/$" 40 & lJ.5 2~7/8" 6.4 2-7/8" 6.a CIW Dual Hanger Crossover, 3-1/2" Bu~es~ Box x 2-7/8" 8xd Pin Kobe 2-1/2", "ALP" Cavity CDDssover, 2-7/8" 8~ Box x 2-7/8" Bu~=s, ;Pin Mule Sho~, 2-7/8" Butge,s Box 5ho~ String C~ Dual Hang~ Crossov,r, 2-7/8" Bu~tss Box x 2-3/8" 8~ hn NO. Depth ID 34.15' [ 8,688' 2.411' 2 8,689' 2.250" 3 8,713' 2.411" 4 $,743' 2,411" 3415' 8,688' 1.995" 9,365' 2.992" 9,380' 2.992° Fill Tagged w/2,35" GR FISH: Baker Model "D" Production Pkr 30' of Throu$1a ~8 gun 4spf 20~ Perfgun w/Collar locater Guibcrson type "A" Wireline pkr, Drld Bridge Plug STIMULATIONS: Zorle E E F 8,688' 8,688' 9-5/$"~ 'BWD' Perm. Packer W/15' Cen~at~d Pup 8e~I Assembly 3/31/95 ~ 10,03!}' WLM 9,380' 12/20/67 10,467' MD 4/25/67 10~467' MD 9/02/75 10,186' MD 12/17/80 10,162' MD 4/6/77 Co~o Che~cal Surfac~ant Water Shut-off PERFORATION DATA Perf Date Proposed New New 12/201~7 Suspended 4/'26/69 Suspended Cmt Sqz'd Cmt Sqz'd 1/7/81 Suspended 1/7/81 Suspended Suspended Top Btm Amt SPF 4 PEll'D = 10,467' HOLE ANi3LE thru Interval ' ~G ~ %~~9,720' ~'"-=~' 9.810' G-4 9,920' 9-4 PropdxawC. doc J AN 2 Co AiasWa 0il & Gas CoDs. ............. An~e G-2 G-3 , i\lt~r~ -ll./r~,~[IthIiltJ"J 7 , I I h~ I , h7, liP(~ 9,780' 60' 9,890' 80' 10.070' 150' 8,800' 8,840' 8,875' 8,900' 25' 9,125' 9,180' 55' 9,200' 0,225' 25' 9,290' 9,315 25' 9.425' 9,4.30' 5' 9,440' 9,480' 40' 9,550' 9,605' 55' 9,685' 9,695' 10' 10,g& 4 12,8&4 12, 10,8&6 "UNOCAL )- ......... Dillon Well No. 4. Hydraulic Workover Procedure Revision III 1/20/98 Objective: Pull completion, run an EZSV Bridge Plug to isolate the Hemlock and complete as a dual string Kobe Completion in the Tyonek E and F. BHP of the Hemlock is 2,700psi at 9,400' TVD. Measurements of 150 PPM H2S have been taken from the well. Prepare Well for Workover: . Circulate at least one full tubing and annulus volume with Diesel to displace any remaining produced fluid from above the packer. Note: If unable to circulate, it will be necessary to rig up APRS and run a 1-9116" x 1', 5 spf tubing punch. Rig Up HWO: Note: Contact AOGCC 24 hours prior to testing BOPE (279-1433) . . , . , . . Hold safety meeting with crews and discuss presence of H2S and use of Fresh Air Breathing Systems and the Unocal Alaska H2S Contingency Plan for Hydraulic Pulling Units. Lay out surface equipment. RU and circulating system per attached layout. Secure all lines with chains. Pressure test circulating system to choke to 3,000 psi. Pressure test down stream of choke to 2,500 psi. Set 3-1/2" nominal Cameron Type "H" BPV's. Have Production check for H2S in the well head room. Ensure that SCBA's are available for all hands working in the wellhead room. Verify that well is dead. Have Wellhead Service Rep. Verify that all pressure has been bleed from all lines and voids associated with the tree, seal flange, tubing spool immediately prior to removal. Nipple down flow lines and tree. Verify Tubing Hanger Lift Thread Connection and ensure that any ports in the hanger are properly plugged. Blind flange flowlines per UNOCAL lock out tag out procedure. NU BOP's. BOP's to be configured with 3-1/2" single rams in the top cavity and blinds in the bottom cavity. See attached BOP Stack Layout. Install work window. Pull BPV's and set two-way check valves. Pressure test BOP Iow / high to 250 psi/ 3,000 psi. Pull two way check valves. Dillon 4d.doc 1/20/98 UNOCAL Dillon Well No. 4 Hydraulic Workover Procedure Revision III 1/20/98 10. Complete rig up of HWO unit and associated equipment. Rig up Secorp's Cascade Fresh Air Breathing system H2S Monitoring System and test. Ensure all safeguards are met for a safe operation with adequate fall protection and spill prevention. Check stack bolts once per tour and ensure bolts remain properly torqued. 11. Hold Pre-well safety meeting. Brief crews on safety and environmental concerns. Accept HWO unit. Workover Pull Completion: 12. Engage the short string hanger with 3-1/2" Landing Joint. Back out hanger hold down screws. 13. POOH with 3-1/2" short string. The pipe is not expected to have BaSO4 scale. However the tubing will be checked for NORM with a LUDLUM Monitor. Norm pipe to be properly marked and handled in accordance with UNOCAL's NORM pipe handling procedures. (Attached to end of procedure) 14. Engage the long string hanger with 3-1/2" Landing Joint. Back out hanger hold down screws. PU hanger assembly and Monitor well. 3-1/2", 9.2#, N-80 Tube Body Yield is 207,000#. Maximum pull is 165,600# (80% Yield) 15. Pull seals from packer. 16. POOH with completion. 17. Run wear bushing. Contingency for being unable to pull seals from the seal assembly: A. Rig up APRS on the long string with a full opening safety valve, pump in sub, lubricator. B. MU 2.70" O.D. jet cutter for 3-1/2", 9.2# tubing. RIH to top of tubing bridge plug at 9,326'. With tension in the long string, cut the tubing as close to the bridge plug as possible. (If this contingency is necessary, the 9-5/8" EZSV will have to be set immediately above the tubing stub). POOH and RD APRS. C. POOH with 3-1/2" Long String. Dillon 4d. doc 1/20/98 UNOCAL Dillon Well No. 4 Hydraulic Workover Procedure Revision III 1/20/98 Set EZSV: 18. Rig up Schlumberger E-Line unit. Verify that Schlumberger has the proper fishing tools for all tools RIH and that they are compatible with the slickline unit on board. 19. Make up Junk Basket and an 8" Gage Ring (The 9-5~8" EZSV has a Max. O.D. 7.75"). Run in hole to top of packer at approx. 9,380'. POOH. 20. MU 9-5/8", 40#, HES EZSV, dressed with a bridge plug kit (rated to 7,500lbs Differential), SWS 'CP' Setting tool, & CCL. RIH tag tubing stub. Pick up and set Bridge Plug at approx. 9,375'. Ensure that retainer is not being set in a collar. POOH with Setting Tool. 21. Pressure test 9-5/8" and EZSV to 1,500 psi for 15 minutes. Contingency Clean Out Run (If unable to get gage ring down) A. B, C. Pick up the following BHA: - Bit, 8-1/2", 4-1/2" Reg Pin - Casing Scraper, 9-5/8", 43.5,40 #, 4-1/2" Reg Box x 4-1/2" Reg Pin - Crossover, 4-1/2" Reg Box x 3-1/2" IF Box RIH with 3-1/2" Drill Pipe to top of packer at 9,380'. Break circulation pumping at 3 bbls/min. Circulate at least one hole volume or until clean. POOH with clean out assembly. Run New Completion: 22. Change Upper rams to 13-5/8" x 2-7/8", 5M Dual Rams. 23. Retrieve wear bushing. Shell test BOP's to 3,000 psi. 24. Rig up 2-7/8" Dual tubing handling equipment. 25. Pick up the following completion. Pipe dope pin connections only using a paint brush with APl Lead Free Modified. BHA and Long String Wireline Re-entry Guide, 2-7/8" Buttress Box 1 jr. 2-7/8", 6.4#, L-80, Buttress SC Tubing Crossover, 2-7/8" Buttress Pin x 2-7/8 EUE 8 rd Pin KOBE, 2-1/2", Type "ALP" Cavity Long String: Crossover, 2-7/8" EUE 8 rd Pin x 2-7/8" Buttress Box 2-7/8" 6.4#, L-80, Buttress SC Tubing to surface 3-1/2" Dual Half of 11" 'DCB' Split Hanger Dillon 4d.doc 1/20/98 UNOCAL Dillon Well No. 4 Hydraulic Workover Procedure Revision III 1/20/98 Note: 26. 27. 28. Short String Crossover, 2-3/8" Buttress Pin x 2-7/8" Box - 2-7/8", 6.4#, L-80, Buttress SC Tubing to surface - Space out pups as required - 3-1/2" Dual Half of 11, 'DCB' Split Hanger Verify that the Long String and the Short String are being run properly in relation to the tubing spool and the surface production piping. RIH with assembly torquing connections to make up marks on buttress connections. Drift all 2-7/8" tubing joints to 2.347". RIH and space out/land completion. It is preferential to have the long string in tension relative to the short string. Engage hold down screws. MU 2.347" gage ring on .125 slickline, lubricator, pump in sub, and full opening safety valve on long string. Install safety valve on top of short string. 29. RIH and ensure tubing is clear of obstructions. Note Fluid Level. POOH with slickline. 30. 31. 32. 33. Make up Standing Valve on running tool. RIH with standing valve to fluid level. Once in fluid "shake ofF' standing valve. POOH. (Do not rig slickline completely down until tubing and standing valves are successfully tested.) MU kelly line on long string. Open short string valve and line out to tank. Circulate diesel down long string and establish returns from short string. Shut in short string valve and pressure test tubing with test pump to 4,000 psi against standing valve. Release pressure and remove valves. RD & Release HWO 34. Set BPV's. RD HWO unit. ND BOP's. 35. NU Tree. Pull BPV's and set 2 way checks. Pressure test tree to 5,000 psi. Pull 2-way checks. 36. NU flowlines, power oil system, and pressure test to 5,000 psi. 37. Turn well over to production. 38. Release HWO Unit. 39. Unload diesel from well to underbalance. Dillon 4d.doc 1/20/98 UNOCAL Dillon Well No. 4 Hydraulic Workover Procedure Revision III 1/20/98 Perforate Tyonek (Procedure to Follow) The following intervals are to be perforated using 2-1/8" Hollow Carriers, 4spf, 90 deg: Zone Bottom Top Length Tyonek F 9,315' 9,290' 25' Tyonek F 9,225' 9,200' 25' Tyonek F 9,180' 9,125' 55' Tyonek E 8,900' 8,875' 25' Tyonek E 8,840' 8,800' 40' Net Interval: 170' Dillon 4d.doc 1/20/98 WELL DILLON ~ HYDRAULIC WORKOVER PLATFORM DILLON 28.54 15.54 2.16 2.23 4.45 4.20 2.50 14.50 3" RLL DRIWNC SPOOL 13 5/8' 5M x 13 5/8" 5M DRIWNG SPOOL 13 5/8' 5M x 13 5/8" 5M WITH 4 1/16" 5M OUTLETS ~NUI..AR PREVENTI[R I-fYDRIL CK l~ 5/s' SM DOUBLE GATE NL SHAFFER RISER 1,5 5/8' 5M 13.00 1.00 ADAPTER SPOOL 13 5/8" 5M x 11" 5M CIRCULATII HYDRAULIC PLATFORM ;SYSTEM WORKOVERS DILLON PANIC UNE DSR CHOKE / % 10 PRODUClION HOSE HOSE FROW PLATFORW PITS # FILL HOSE I I 4" REIVRN 5x6 6" SUCTION 50 50 BBL. BBL. 2', 5M KELLY HOSE [ .L TRIP TANK [oo01 OPI TRIPLEX MUD PUMP HOSE (TO PLAT PR'S) 2", 5kt 1502 /nleJ I CIRCULATING S' PLATFORM TEM, FOR HWC DILLON 3', 5~ FLANGE X 2", 5U 1502 UNION Z-Ji~UANUAL CHOKE ~ 2'. 5U HOSE " e/1502 UNION TO PRODUCTION ANNULAR AND DOUBLE GATE ANUORED HOSE 4", 5U UANUAL [~ 4', 5U HYD I°1 Iol FLOW UNE 3', 5~ FLANGE X :~3", 5U 2', 5U 1502 UNION ! KELLY UNE 2' 1502 5M LOTORC 2', 5U STEEL w/1502 UNION FROU PUUP /Ill# I/,J~/dr~I).~, OVERHEAD VIEW FROM WELL HYD CHOKE GAUGE VALVE AT gO DEGREES TO PRODUCTION PANIC LINE 115" To PRODUCTION SIDE VIEW PANIC LINE 5 1/8", gM CHOKE MANIFOLD PLATFORM DILLON STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: ,/r,, 110' KB, MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service:_'.~i~ ~" SMGS Unit / Dillon Pltf. 4. Location of well at surface 8. Well number _.~1, ,I 743' FSL, 1818' FWL, Sec. 35, T8N, R13W, S.M.~ ~' ~ .... At top of productive interval 9. Permit number 2134' FNL, 1990' FWL, Sec. 35, T8N, R13W, S.M. 67-58 At effective depth 10. APl number 50-733-20047-00 At total depth 11. Field/Pool 1791' FNL, 2136' FWL, Sec. 35, T8N, R13W, S.M. South Middle Ground Shoal/Hemlock 12. Present well condition summary Total depth: measured 10,550' feet Plugs (measured) true vertical feet0RI$1NAL' Effective depth: measured 10,467' feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth Structural 329' 20" 625 sx 329' Conductor 1995' 13-3/8" 1822 sx 1995' Surface ~. ~ Intermediate ~-' ~:/:~ '~ 'i'~ 199 Production 10,515' 9-5/8" 1450 sx 10, 515' .0il & Liner Perforation depth: measured Cmt Sqzd Cmt Sqzd . 9425'- 9430' 9440'- 9480' 9550'- 9605' 9685'- 9695' 9720'- 9780' 9810'____ ra~20'- 10,070' true vertical Tubing (size, grade, and measured depth) LS: 3-1/2", 9.2#, N-80, Butt @ 9430' SS: 3-1/2", 9.2#, N-80, Butt @ 68° Packers and SSSV (type and measured depth) Baker Mod"D" Perm Pkr @ 9380' 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: 14. Estimated date for commencing operation 15. Status of well classification as: October 10, 1997 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: /,~~~ ~'~\/"--~ Title: OY;lti"'3 //~%~'L~" Date: [~..~{ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test j Location clearance, ,~"'~ '"* / Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Proposal Summary F1 Dillon D-4 1 Set 3-1/2" Magna Drill BP in tail pipe @ 9420' (10' above EOT). Isolating Hemlock conglomerate. 2 Circulate/displace 40 bbls of class G cmt (160 sx) down tbg & out into 9-5/8" csg/tbg annulus through the Kobe Cavity Pump @ 9351'. Top of cmt in csg/tbg annulus @ (+-) 8750'. 3 Run CBL to Confirm cement height in tbg/csg annulus @ 8750'. 4 Perfoate Tyonek "F" sands 9150'- 9177' & 9133'- 9145'. Perforate Tyonek "E" sands 8873'- 8895' & 8813'- 8840'. 5 Install "Concentric Monobore" Pump System @ 8730'. 6 Place well on production. r. Ul'-~-8'( THU U~: 3( UNOCALe RKB to TBG Head = 34.16' T ,ee =onnectlot 1 PBTD = 10,467' TD = 10,550' HOLE ANGLE thru Interval = 18.~ UNOC~L fi~E'l' Gfl~ GRk ': D-4.DOC i i i i . ILII I J bHX NU, Ur'/U6 Middle Ground Shoal Well # D-4 Completed 2/17/83 Illll . I Illll II I LS SS SIZE CASING AND TUBING DETAIL WT GRADE CONN ID 20 13-318" 61 K-55 12.515 9-5/8" 40 & 43.5 N-80 8rd LT&C 8,755 Tubingt 3-1/2" 9.2 N-80 Butt. 2.992 3-1/2" 9.2 N-80 Butt. 2.992 TOP BTM. Surf 329' Surf. 1995' Surf 10,515' 0' 943 o' 0' 6}1' E G1 ] G1 NO. Depth I,D 34,15 I 9351' 2.687 2 9377' 3 9386' 4 9380' 4.00 5 9430' JEWELRY DETAIL Item CIW Dual Hangm' Kobe 3 E Pump SN 2344, wl six 1" diameter holes. 24.74' long 8,47' Blast Joint Locater Seal Assy. w/12,65' of seals Baker Model "D" Retainer Production Pkr, Baker Mule shoe ~ G3 ; G3 Zone Top, Fill Tagged w/2.38" GR FISH: 30' of Through tbg gun 4spf 20' Peff gun w/Collar locater ~uiberson type "A" Wir~line pla'. Dr[d Bridge Plug STIMULATIONS Corco Chemical Surfactant Water Shut.off tr~am~nt 3/31/9~ ~' 10,039' WLM 12/20/67 ¢~ 10,467' MD 4/25/67 ~. 1.0,467' MD 9/02/75 Or. 10,186' MI.} 12/17/80 O 10.162' MD 4/6/77 - PERFORATION DATA Accum Last Btm Amt SPF Perf Date Present Condition G-1 9,425' 9,430' 9,440' 9,480' G-2 9,550' 9,605' G-3 9,685' 9,69S' G-3 9,720' 9,780' 9,810' 9,890' G-4 9,9_20' ' 10,070' 5 40 10 60 80 150 4 12/20/e7 Open f/Prod 4 4/26/89 Open f/Prod Cmt Sqz'd Cmt Sqz'd 10,8 & 4 1/7/81 Open f/Prod 17., 8 & 4 1/7/81 Open f/Prod 12, 10, 8 & 6 Open f/Prod J .. ,, i iii tllll . 22 - ~ RECEIVrc. D DATED: 5/23/97 ASSEMBLED BY STEVE TYLER L~T-22-BY THU UNOCRL fl$SET GR$ GNP FRX NO, 9072637874 Y, U3/U~ Middle Ground Shoal Well # D-4 Completed ZI17153 PROPOSED MONOBORE COMPLETION RKB to TBG Head = 34.15' Tree 85~4' 8578' 8600' Kobe Fishing Neck ~ tocal Packer Cup ~ Trico Type "A" Jet Pump Punched Perfs. '"'..~ Standing Valve w/Kobe Kn~ko---~-~ WLR Otis 3-U2" "RCP" Tbg P~ w/2.38" Upper Seal Bo~e. Min ID thru of cmt @ 8600' 9342' 9346' 9351' E Zone 881~-8840' 8873'-8695' F Zone 9133"9145' 9150' -9177' ~ E-Line Set Drillable Bridge Plug, rated to 5,000 psi di ,Cmt Wiper Plug ~,[[ne set 3-1/2" EZ Dritl Squeeze~ 9380' E-Line Set (2-7/8" / 3-1/2") Magna Range Drillable Bridge Plug, to 5,000 psi differential. 2,30 OD D-4.DOC RECEIVED 23 1997 Gas ,Cons. ~ommis~ DATED: 5/23/97 ASSEMBLED BY STEVE TYLER STATE OF ALASKA "-"~ 0I G IN OIL AND GAS CONSERVATION COMb,..,iON APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon __ Suspend __ Operation shutdown .._. Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other. X Name of Operator ....... ~5. _e_ f ~ I' 6. Datum elevation (DF or KB) Union Oil 0ompany of californl~ ~hent.,~.. Exploratory __ 10 _'3 ' R-'{--~ MST-- feet / 3. 5 c,_,~ oS~graphic __ 7. Unit or Property name Addres_ .o.~S_ Box 196247, Anch., AK, 9 1~, .... Service__ .qMC'.R llni t 4. Location of well at surface Leg iCl, Slot 2, Platform Dillon 748' FSL, 1820' FWL, Sec. 35, T8N, R13W, SM At top of productive interval 2134' FNL, 1990' FWL, Sec. 35, T8N, R13W, SM At effective depth 3487' FSL, 2104' FWL, 'Sec. 35, T8N, R13W, SM At total depth 3505' FSL, 2134' FWL, Sec. 35, T8N, R13W, SM 8. Well number 4 9. Permit number 67-58 10. APl number 50-- ~33-20047 11. Field/Pool SMGS/Hemlook 12. Present well condition summary Total depth: measured true vertical 10550' feet 10100' feet Plugs (measured) 10,467'-10,550' Effective depth: measured true vertical 10467' ~ 10022' ~et Junk (measured) Casing Length Size Cemented Structural Conductor 2'88 ' 20" 625 SX Surface Intermediate 1957 ' 13-3/8" 1822 SX Production 10479' 9-5/8" 1450 S× Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) MeasumddeCh ~ueverticaldepth 329' 329' 1995' 1975' 10515' 10067' See attachment 3-1/2", 9.5#, N-80, 3-1/2", 68' RECEIVED DEC - 9 Alas!~t.0il & Gas Cons. C0mmissi0 9 4 3 0 ' Anchorage Packers and SSSV (type and measured depth) Baker Model "D" @ 9399' 13. Attachments Description summary of proposal __ Detailed operations program ..~ BOP sketch __ 14. Estimated dateOctoberf°r commencing8operation, 19 91 ii 15. Status of well classification as: 16. If proposal was verbally approved Oil __ Gas __ Suspended _ Name of approver Date approved Service 17. I hereby c(e~,fy that the f~goir~t~correct to the best of my knowledge. Signed "~~ ~ ~ ~'~H Title REGIONAL DRZLLING ]v[~~R I I - 2_. 5 -% \ (..J ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No.,.=,, .~,, I ,--;/ Plug integrity __ BOP Test __ Location clearance , Mechanical Integrity Test ~ Subsequent form required 1"~'- ~°¢r ~ ORIGINAL Approved by order of the Commissioner LON,N~E C. SF~ITH ....... Commissioner Date FOrm 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Alaska 0il & Gas Go~s. AnchOrage Pertinent Dote: Iff ore,Icl.: IUoI Potentlol: IUal Stlmulodon: ~ Dot&' ~*6d IntE(val~: nd SOUTH MIDDLE OROUND SHOAL. ADL 18746 WELL NO. 4 HEMLOCK CONOLOMERATE PLATFORM DILLON 10/~W7 Lei 1, Slot :2 748' FSL. 1820° PilL, Sea. 3~. TaN, R13W. $.U. TO - 3505' FSI,. 2137' FWL, Sea. 35, TaN. RI3W, $.U. 110' KB 10.150' 1M3 1OO98' 10487' I~D 10181' 20". 8~ and g6~l Codng let ~t 228' with 625 ix oenmnt 13 ~VS". 54.5~ Co,In. II Nt et 10~' Mth 1822 mc Mment O ~(8'. 40 end 43.51~ N-80 and S-eS toeing let ot 10515' I dth 1450 ix oenmnt 0-1: 0-3: e712-e78o' g81o-gs9o' 0--4: 502o-1oo73' · Cement &quNzed 2773 BOPD, 203 BWIK). 1.1 IAICF' Nont Non4 IEL-SP, BHO- OR 12/1/67 Oamma .Ray 11/4/74: DlffmlntJd Timpirltm'o and OommQ Roy e/11/76 Oanvno Ray Oanuno Ray 1/26/8S · CompleUon Record = - : ..... ~c)ng String: 1. ColTwon Duol IX:B tubing heng.r 2. 3 1/2" g 1/2t N-B0 BuUreM 3. Kob~ 3" '~' ~HX a/h 2~44 (vvl~up) 4. 3 I,/2" 8RD end 3 I/2" ButIT~I XO 5. 4 I/2" Bigot Joint 8. Boktr Locotor ?. Bokir 4.?5" Sial omlembl¥ 8. 3 I/2" Buttreot tubing g. Uulllhoe short Sbtng:A. ~ 1,/2" ButtrMI tubing B. 3 1/2" Buttmml Collar (As mn Z,'I Dopth 35' 9352' 0377' g377' g386' 0387' 0300' g420' 0430* oeds csJ~ 320. 1005' 67' 68' Boklr Idod~l D Paok4r 0420' g480' 0688---0800' 0712' OOgO* gO20-.-10073' Tagged F~! · lo.23o' 12/Io/84 I' ........... I 10467' ~ 10~' ~.5~ C~ 1051~' SOuth Mid-" - u~e Ground Shoal ADL 18746 Well No. 4 Proceclure for SUSpen(//ng an(/freeze protecting Well: 1) Reverse the hydra - freezin,., ~. .... ulic PUmp o,,, ..-~- ~ uy power oil ~, ,~.;_ .., u~ me hole. Long · -- ,,,s Point. string Will be Protected against Circulate POwer oil into 9 5/8" casing ,X, tubing annulus taking returns u string. Short string point, and tubing X 9 5/8 annulus Will be freeze r~,~, ....P Short Close all Valves on the well head. ,"' ~,,~cmc/at this Install gauges on the tubing and 9 5/8" casing X tubing annulus. RECEIVED DEC - 9 ~,991 Alaska 0il & (Jas Cons. Commission Anchorage L. A. Darsow District Superintendent March 11, 1983 File' LAD-301-WF Amoco Production Company (USA) Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AlaSka 99501. Dear Sir: Subsequent Notice SMGS Unit Well No. 4 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to the repair work done on SMGS Unit Well No. 4. The repairs were made and the well was returned to production. The well is currently producing 50 BOPD, 152 BWPD, and 21 MCFD of gas. Yours very truly, L. A. Darsow District Superintendent Attachments MTS:seh MAR .~ ? 1983 Alaska 0il & Gas Cons. Commissior~ Anchorage STATE OF ALASKA ALASKA Ol1_ AND GAS CONSERVATION CO,v,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator gmoco Production Company 3. Address P.0. Box 779, ^nchorage, ^laska 99510 4. Location of Well Leg 1, Slot 2, SMGS Platform Dillon 2137' FWL, 3505' FSL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 110' KB, MSL I 6 . Lease Designation and Serial No. ADL 18746 7. Permit No. 67-58 8. APl Number so- 733-20047 9. Unit or Lease Name SMGS Unit 10. Well Number' 4 11. Field and Pool South Middle Ground Shoal Heml ock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made ~] Other [] [] Other [] Pulling Tubing ~] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company performed the following work: 1. Determined wellhead pressure, mixed brine, and killed well. 2. Set back-pressure valves, nippled down tree, nippled up BOP's, and tested to 2500 psi. Pulled back-pressure valves. 3. Pulled tubing and bottomhole assembly. 4. Ran in new bottomhole assembly and tubing. Mule shoe set at 9430' and bottomhole assembly set at 9377'. (Packer previously set at 9380' during workover performed in December 1980.) 5. Returned well to production. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ECEIVED MAR 1 }' 1983 Signed ~'F~ ~---~C~C)t-~.~k [,~.~ The space below for Commission use Title District Superintendent Conditions of Approval, if any: Approved by By Order of COMMISSIONER the CommIssion Form 10-403 Rev. 7-1-80 Subrm! "Intentions" m Tr~phcate and "Subsequef}! Repor ls" in [.)upl~cale STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Company 67-58 3. Address 8. APl Number P.O. Box 779, Anchorage, Alaska 99510 5o-733-20047 4. Location of Well Leg 1, Slot 2, SMGS Platform Dillon 2137' FWL, 3505' FSL, Sec. 35, T8N, R13W, S.M. 5. Elevation in feet Jindicate KB, DF, etc.) 110' KB, MSL J 6 . Lease Designation and Serial No. ADL 18746 12. 9. Unit or Lease Name SMGS Unit 10. Well Number 4 11. Field and Pool I South Middle Ground Sh0al Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation E] Abandonment E] Repair Well [] Change Plans [] Repairs Made ~] Other [-1 Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date ot starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company performed the following work: 1. Determined wellhead pressure, mixed brine, and killed well. 2. Set back-pressure valves, nippled down tree, nippled up BOP's, and tested to 2500 psi. Pulled back-pressure valves. Pulled'tubing and bottomhole assembly. Ran in new bottomhole assembly and tubing. Mule shoe set at 9430' and bottomhole assembly set at 9377'. (Packer previously set at 9380' during workover performed in December 1980.) Returned well to production. ~~'~ i~'~' ~V~ MAR . . 14. i hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Title District Superintendent Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commlsston Dar,, ~ Form 10-403 Rev. 7-1-80 Suhm~! "Intentions" tn Trlphc;ti'e and "SLibse(jue. t~! Ri?polls" tn [.)HI311C,:IIe L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 February 11, 1983 File- LAD-165-WF Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent SMGS Unit Well No. 4 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to replace the bottomhole assembly in the subject well. A recent pump change indicated internal damage to the bottomhole assembly. The well is currently shut-in and is expected to produce 50 BOPD, 1250 BWPD, and 20 MCFD of gas when put back on line. Therefore, we plan to perform this work at our earliest convenience. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment MTS/seh Alaska Oil & Gas 0oas. O°mr~issior~ Anchorage STATE OF ALASKA "'", ALASKA ~,~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] coMPLETED WELL~ 2. Name of Operator 7. Permit No. Amoco Pr0duction Compan~v 67-58 3. Address 8. APl Number P.O. Box 779, AnChorage, Alaska 99510 50_133-20047 9. Unit or Lease Name SMGS Unit OTHER [] 4. Location of Well Leg 1, Slot 2, SMGS Platform Dillon 2137' FWL, 3506' FSL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 110' KB, MSL 12. 6. Lease Designation and Serial No. ADL 18746 10. Well Number 4 11. Field and Pool South Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well t~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-4.07 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to' 1. Determine wellhead pressure, mix brine, and kill well. e Set back-pressure valves, nipple doWn tree, nipple up BOP's, and test to 2500 psi. Pull back-pressure valves. 3. Pull tubing and bottomhole assembly. 4. Run in new bottomhole assembly and tubing. Se Return to production. RECEIVED F E B I 5 1983. o~l~ 3~/J'~'~laska ~o~_. , . Anchorage ~ ~o~ ~o./~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ .. _ Title District Su_erintendentp The space below for Commission use Date Conditions of Approval, if any: Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent April 2, 1981 File: LAD-436-WF 1-1 I Amoco Production Compa. Post Office Box 779 J FILF: Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent ~epor.~._~rr Repair Work Platform Dillon, Cook .Inlet, Alaska Attached in duplicate is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells, outlining the recent repair work. The work was completed January 18, 1981, and the subject well operates as a pumping oil well. Yours very truly, L. A. Darsow District Superintendent Attachment KEO/klt STATE OF ALASKA ALASKA ."~: L AND GAS CONSERVATION C~.,,'/IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER I-I 2. Name of Operator 7. Permit No. Amoco Production Company 67-58 3. Address 8. APl Number P. O. Box 779, Anchorage, Alaska 99510 50-7332004700 4. Location of Well Leg l, Slot 2, SMGS Platform Dillon 2137' FWL, 3506' FSL, Section 35, T8N, R13W, S.M. 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 4 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 1 lO' KB, MSL I SMGS 18746 12.Check Appropriate Box To Indicate Nature of Notice, Report, or )_.tb.e[Dat. a ............... ----.____. NOTICE OF INTENTION TO' suBSEQuENT REPORT OFL) (Submit in Triplicate) ~"' ' (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [X] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [X~ Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) South Middle Ground Shoal [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any' proposed work, for Abandonment see 20 AAC 25.105-170). The following work was performed during the period December 4, 1980 to January 18, 1981: 1. Pulled tubing and cleaned out to 10,162' MD. 2. Cement squeezed G-2 and G-3A zones, 9550-9605' MD and 9685-9695' MD, respectively. 3. Reperforated G-3B and G-4 zones, 9725-9880' MD and 9920-10,073' MD, respectively. Ran new 3-1/2" tubing and hydraulic pump cavity. e Returned well to production. APl? .. $1981 14. I hereby certify that the [oregoing is true and correct to the best of my knowledge. Signed , , _ Title District Superintendent Date The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent January 9, 1981 File- LAD-O46-WF Amoco Production Compa j R~S [fNG Post Office Box 779 Anchorage. Alaska 99510 907-272-8471 Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AlaSka 99501 Dear Sir: Subsequent Report of Repair Work SMGS Unit Well No. 4 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells for SMGS Unit Well No. 4. The repair work was performed during the period December 4, 1980, and the subject well was returned to production December 20, 1980. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment KEO/kl t gi.~ska Oil & G~ ~ ,,s bens. Cota~jSSio~ Anchorage ~'~i STATE OF ALASKA ALASKA ~IL AND GAS CONSERVATION C~,MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name o_f Operator 7. Permit No. Amoco Production Company 67-58 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 50- 133-20047 4, Location of Well Leg l, Slot 2, SMGS_Platform Dillon 2137' FWL, 3506' FSL, Section 35, T8N, R13W, S.M. 5, Elevation in feet (indicate KB, DF, etc.) llO' KB, MSL , GL 6. Lease Designation and Serial No. ADL 18746 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 4 11. Field and Pool South Middle Ground Shoal 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · · Amoco plans to reperforate the following intervals' G-3B Zone: 9725-9880' MD G-4 Zone' 9920-10075' MD Return the well to production. Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,-~[ .~~'-~(~:~-~--., ~ ~ ,. The space below for Commission use Title District Superintendent Date 1/9/81 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER Approved '~o'~¥ Returned By Order of the Commission Date ') '''%) 7_ -~} Submit "Intentions" in TripliCate and "Subsequent Reports" in Duplicate ~ STATE OF ALASKA ALASK' 3IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL)t~ OTHER [] 2. Name o_f Operator 7. Permit No. Amoco Production Compan.v 67-58 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 so- 133-20047 4. Location of Well Leg 1, Slot 2, SMGS Platform Dillon 2137' FWL, 3506' FSL, Section 35, T8N', R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) llO' KB, MSL GL 6. Lease Designation and Serial No. ADL 18746 12. 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 4 11. Field and Pool South Middle Ground Shoal Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations I-'1 Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). e Amoco plans to reperforate the following intervals: G-3B Zone: 9725-9880' MD G-4 Zone: 9920-10075' MD Return the well to production. SuBseqtxent 'Win:'!.': -',~- _~'/ Alaska Oil Lt G~s Cons. Corr~mJssior~ Anci~.orage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below fOr Commission use Title District Superintendent Date 1/9/81 Conditions of Approval, if any' Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER ' ApproVed ~e.~urnec~ By Order of the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent January 9, 1981 Fi le' LAD-O45-WF Amoco Production Compa Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 ...... COMM__~ ~-E-~ENG.. ! - ,v 4 ENG I,,,I 1 GEOL _ 1 3 J STAT TEC I STAT TRC · CONFER: FI!. F: , , Mr. Hoyle H. Hamilton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Notice of Intent to Reperforate SMGS Unit Well No. 4 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells, for reperforation of the subject well. We plan to reperforate this well in the G-3B and G-4 zones to increase oil production. We plan to perform this work at our earliest convenience. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment KEO/klt RECEIVED .......... Commission Anchorage ~ STATE OF ALASKA ALASK/~ JIL AND GAS CONSERVATION C~MMISSION 'SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL;I~( OTHER [] 2. Name of Operator Amoco Production Company 3. Address P. O, Box 779, Anchorage, Alaska 99510 4. Location of Well Leg l, Slot 2, SMGS Platform Dillon 2137' FWL, 3506' FSL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 7. Permit No. 67-58 8. APl Number so-133-20047 9. Unit or Lease Name South Middle Ground Shoal 10. Well Number 4 11. Field and Pool 110' KB, MSL GL ADL 18746 South ._Mi_dd___l~e Ground Shoal 12. Check Appropriate Box To Indicate Nature of Notice, RepQr. t~-orOther Data NOTICE OF INTENTION TO: ,~' SUBSEQUENT REPORT OF: ~/) (Submit in Triplicate) ~ .... (Submit in Perforate [] Alter Casing [] t Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made I-X] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · 2. 3. 4. Pulled tubing and cleaned out to 10,162' MD. Cement squeezed G-2 and G-3A zones· Ran new tubing and production equipment. Returned well to production December 20, 1980. Apchora§e 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~. ~[_[~.~t.~..~ _. Title District Superintendent The space below for Commission use '~ ~.~,~,4,,,, ~, Date 1/9/81 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent September 19, 1980 Fi le' LAD-981-WF Amoco Production Co/q~ Post Office Box 779 Anchorage. Alaska 99510 907-272-8471 J STAT TEC -~"I STAT TE~-- ~.. 'CONFER: FILF: Mr. Hoyle H. Hamilton, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent to Perform Work SMGS Unit Well No. 4 Platform Dillon, Cook Inlet,~Alaska Attached in triplicate for your approval is our State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to perform repair and cement squeeze work on the subject well. The purpose of this work is to repair faulty bottomhole equipmentand shut off water production from the G-3A and G-2 zones. We plan to start this work in approximately three weeks. Yours very truly, L. A. Darsow District Superintendent Attachment KEO/klt Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION cOMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this fOrm for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. ~/~LLLl~! GAS D OTHERWELL 2_ NAME OF OPERATOR Amoco Production Company 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 99510 4o LOCATION OF WELL Atsu.ace Leg l, S10t 2, SMGS Platform Dillon 2137' FWL, 3506' FSL, Sec. '35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) llo' KB, MSL GL 14, Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20047 6. LEASE DESIGNATION AND SERIAL NO. ADL 18746 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME South Middle Ground Shoal 9. WELL NO. 4 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, T8N, R13W, S.M. PERMIT NO. 67-58 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [_._._J PULL OR ALTER CASING L.~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other} Reduce Water' Production SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent details° and give pertinent dates, including estimated date of starting any proposed work. The subject well has been shut-in since August 21, 1980 due to a faulty bottomhole: assembly. AmOco plans to repair the well and reduce two water production zones as follows' · 2. 3. 4. 5. 6. 7. Pull tubing, bottomhole assembly, and mill out packer· Clean out to 10,187' MD. Cement squeeze G-3A and G-2 zones. Drill out cement and retainers. Set new packer. Run new bottomhole assembly and 3" pump. Return well to production. Subsequent Work Reportecl on Form No./~"~O~ Dated Z_/.~ ~.~/ 16. I hereby certify that the foregoing is true and correct S,*NED. 6:27"~'V~- -T,TLEDistrict Superintendent DATE September 19, 1980 . .. DATE Appmv~ Subsequent Work Beported Eeturn~ ,.,,ruc,,on, On .eve _ SCHLUMBERGER OFFSHOF¢~' SERVICES /~'% Division of Schlumberger Limited ~ HOUSTON, TEXAS 77001 PLEAII£ Fla..PLY 70 APR I L 9, 1980 ,c.L. .... ~,. o .... o.. ..... c,, 500 W INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99502 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA Attention: 99501 Gentlemen: 1 RFOLDED SEPIA Enclosed~)e_p ~)j:~rints of the GAMMA RAY, ENGINE, ERED PP-,~TION LOG n' Compon~ AMO RO UCTION CO ,WelI SMGS a-i5 D-13,(~]~__~ b-8' R-D-~--~S'#11 Field ~OUTH HI.DDLE GROUND SHOAL,county. KENAI .;~ALAS4A ' Additional prints are being sent to: prints prints , prints prints . prints prints prints prints The film is RETURNED TO AMOCO We appreciate the privilege of serving you. Very truly yours, /'' .~ (. ~ ' r , '~ ~ SCHLUMBERGER OFFSHORE SERVICES SCHLUMBERGER OFFSHO A ~Division of 5chlumberget--~r~_.__~.~~J fo,,l CO,M..M MAR CH 26, 1980-J ? ~ 1 ENG~ - // ~E~. INTERNATIONAL AIRPORT [ ~--~-~~RAGE, ALASKA 99502 AMOCO PRODUCTION COMPANY ! P.O. BOX 779 "-ANCHORAGE, ALASKA 99501 '- Atlention: RAND! ROSENBURG Gentlemen: Enclosed are~rints of the GAMMA R AY Company/ AMOCO PRODUCTION , Well. SOUTI Field oOUTH MI DDLE GROUND SHOAL, County. KEN: on: Additional prints ore being sent to: 2 BI_' nrints DIVISION PRODUCTION MANAGER D'ENVER DIVISION SEC'UR"'ITY L"IF'E~ B£D'G. DEN'VER ," COLORADO 80202 1 BL nrints CHEVR'ON U.S.A., INC. P.O. BOX 7-839 ANCHORAGE, ALASKA ATT. MR. KIRKVOLD RE 1 I BL prints DIVISION GEOLOGI. ST , EXPLOITAT ION --_ SECURITY LIFE BLDG, '-DENVER, COLORADO 80202 1 BL prints GETTY OIL COHPANY. THREE PARK CENIE~J_~_~E_ 700 .~l 5_1~ AR APAHOJ~_S~ .......... DENVER, COLORADO 802.02 ! BL nrints ~1 BL prints DE.PART~J~'~T OF NATURAL RESOURCES ""~,PH!LLIPS PETROLEUM COMPANY DIVISION OF OIL & GAS CONSERVATION ~800 EAST DORADO PLACE 3pg.!='POR_,C~U?,,IN.E DRIVE 'lI I : i II . I ' ENGLEWOOD' COLORADO 80111 ANCHORAG'E, ALASKA 99501 ~A~TT' MR.' DENNy "--~T._=_ HOYLE HAMi LTON '_____..-.~~'-' : 1i R ! prints ApTIANTI£ RI~HFIFI D CrlMPANY · O o BOX 3160 ANCHORAGE, ALASKA 99501 prints The film is RETURNED TO D E.NV ER AMOCO We appreciate the privilege of serving you. DATE Ancl~ora~e Very truly yours, SCHLUMBERGER OFFSHORE SERVICE5 I)l$'rR i~-T M ANAGJ'JJ L. A. Darsow Area Superintendent December 6, 1977 File: LAD-1008-WF Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 Mr. O. K. Gilbreth, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Report to'Well Work SMGS Unit Well No. 4 Please find attached our State of Alaska Form 10-403 for a water shut- off treatment performed April 5, 1977 in the subject well. Due to mechanical difficulties which developed following the treatment we were unable to'production test SMGS Well No. 4 until late November. For this reason we delayed submitting our "subsequent report" until this date. Attempts to pump test SMGS Well No. 4 during April and May indicated that a tubing leak was probably present. Subsequent pressure testing confirmed a leak. During late September ~he Kobe bottom hole assembly was changed and the tubing leak was repaired to'restore the well to operable condition. Immediately following this work, we experienced a prime mover failure in our hydraulic lift system which required six weeks to' repair and prevented us from pumping Well No. 4. On November 22 we were able toresume producing the well. Yours very truly, L. A. Darsow Area Superintendent Attachment cc: Mr. J. W. Hart, Atlantic Richfield Hr. J. P. Denny, Phillips Mr. Char.les F. Kirkvold, Chevron USA Mr. Walter J. Newman, Getty JSD:klt Form 10-403 REV. 1-10~73 Subml t "I ntentions'" in Triplicate -& "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---', for such proposals.) WELLL..J OTHER NAME OF OPERATOR Amoco :Production Company 5. APl NUMERICAL CODE 50-133-20047 6. LEASE DESIGNATION AND SERIAL NO. ADL 18746 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME SMGS Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, Alaska 99510 4 -. 4. LOCATION OF WELL Atsu~ace SMGS Platform Dillon, Leg 1, Slot 2 743' FSL, 1818' FWL, Sec 35, T8N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, ets) RKB 110' Above MSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 35, T8N, R13W, SM 12. PERMIT NO. 67-58 )orr, or Other Data NOTICE OF INTENTION TO: · TEST WATER SHUT-OFF L.--.--i PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF.' WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTER lNG CASING SNOOTING OR AClDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent details, and give pertinent dates, Including estimated date of starting any proposed work. A cross-link polymer squeeze treatment' was performed Aprll 5, 1977 on the subject well. The treatment procedure is given on the attached page. Productio,m Test Data Prior to work*: 45 BOPD x 1742 BWPD x 62 MCFD (May 21, 1976). After work: 169 BOPD x 1480 BWPD x 42 MCFD (November 30, 1977). *Well was shut-in June 12, 1976 HWOR prior to water shut-off E I\~/ 17~ ~ea~ment being performed. 16. I hereby certify that the foregoing is true and correct , TITLE Area Superintendent DATE~ee~mhmr ~. lq77 (This space for State office use) APPROVED BV CONDITIONS OF APPROVAL, IF ANY: - TITLE DATE See Instructions On Reverse Side Phill. lp,'; WI) Polymer Treatment SHGS Unit Well No. 4 -April 5, ].977 S rep Average Rate (BPbi) H a x i ill u m Pressure (_p. si) ].. Inject filtered Inlet water (FIW) to' establish fa-.te 9 Iuject 25 lb. WD 160 and 5 lb. WD 501 in 50 barrels FIW 3. ]'nj eot 25 lb. WD 120 and 5 lb. WD 501 in 50 barre].s FIW Inject 50 lb. WD 160 and 10 lb WD 501 in 50 barrels FIW 5. tnjeot 50 lb. ~CD 120 and t0 lb. WD 503 in 50 barrels. FIW 6. Inject 25 lb. ~q3 160 and 5 lb. h© 501 in 25 barrels FIW 7. Inject 25 lb. WD 120 and 5 lb. WD 503 in 25 barrels FIW 8. Inject 50 lb. WD 160 aud 10 lb. lCD 501 in 50 barrels FIW 9. tuject 50 lb. WD 120 and 10 lb. WD 503 in 50 barrels FIW 10. Itijcct 50 barrels aluminum (:J. tratc 5 Jh. W1) 50.1. :Ln 25 barrels F.LW 12. Inject 25 lb. lCD 120 arid 5 lb. WD 503 irt 25 barrels FIW 13. Displace with 200 barrels F1W and with 4 gallons/lO00 F-75 surfactant tubing volume 80 barrels 2.0 2600 2.5 2000 2.5 2000 2.5 2400 2.0 2400 2.0 2600 2.0' 2500 2.0 2400 2.5 2300 2.5 2400 2.5 2/, (1() 2.5 2400 .~00' 2700 RECE!V : 9 !977 . ,. O!,,.,is!o'.'t of 0':: ¢, "'-'- L. A. Darsow Area Superintendent February 28, 1977 File: LAD-165-WF Mr. Hoyle Hamilton, Director Division of Oil and Gas Conservation Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 L. Dear Sir: Re: Initial Report SMGS Unit Well No. 4 ~ Attached is Stateof Alaska Form 10-403 for water shut-off treatment on SMGS Unit Well No. 4. Yours very truly, L. A. Darsow Area Superintendent' Attachment MAR 2 ?977 O!vision (~f Oil ......,.- Anchorage. For~ 10-403 REV. 1-:[0-73 Submit "lntentlon.~" In Triplicate & "Subsequent Reoorts" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20047 6. LEASE DESIGNATION AND SERIAL NO. ADL 18746 7. IF INDIAN. ALLOTTEE OR TRIBE NAME 1. OwlELLLE~ WELLGAS e~ OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME -Amoco Production .Company SMGS Unit 3. ,ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 779, Anchorage, Alaska 99510 4 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 4. LOCATION OF WELL Atsurface SMGS Platform Di-llon, Leg 1, Slot 2, .743' FSL, 1818' FWL, Sec: 35, T8N, R13W, S.M. 13, ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 100' above MSL 14. . Check Appropriate Box To Indicate Nature of Notice, Re SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35~ T8N~ R13W~ S.M. 12. PERMIT NO. 67-58 3orr, or other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report an,d Log f, orm.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The subject well has been shut-in due to high WOR since May 1976 when it tested 45 BOPD, 1742 BWPD and 62 MCFD. A Phillips WD polymer treatment is now proposed in an effort to reduce the water-oil ratio. Proposed~Operation: 1. Inject 2. Inject 3. Inject 50 lbs. WD 160 in 50 barrels Inlet water. 4. Inject 50 lbs. WD 120 in 50 barrels Inlet water. 5. Inject 25 lbs. WD 160 in 25 barrels Inlet water. 6. Inject 2'5 lbs. WD 120 in 25 barrels Inlet water. 7. Repeat Steps 3-6. 8. Inject 50 barrels aluminum citrate solution. 9, Overflush with Inlet water. 10. Shut-in for 36 hours. 11. Return to production. 25 lbs. WD 160 (cationic) polymer in 50 barrels Inlet water. 25 lbs. WD 120 (anionic) polymer in 50 barrels Inlet water. RECEIVED MAR 2 1977 D!vision of Oil and O.¢s Co;'~ser',~atioa Anchorag¢ 16. I hereby certify that t~:~fo, regolng is true and correct S,GNEO ~~~---------- TITLE Area Superintendent DATE February 28, 1977 (This space for State office use) Petroleum Englneer See Instructions On Reverse Side ~rch ~, 1977 DATE Co. Relurned U b~ F) 0 U ~ Submit "Intentions" in Triplicate ¥: & 'iSubsequent Reports" in Duplicate STATE O,F ALASKA OIL AND GAS CONSERVATIONi ,COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to de~pen or plug back to a diffierent reservoir. Use "APPLICATION FOR PER1VIIT--" for such proposals.) OIL WELL WELL QTHER 2. N~VIE OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 99501 OKG API NU1W_ERICAL CODE K~.~' 50-133- 20047 HWK _ LEASE DESIGNATION A_ND ADL- 18746 4. LOCATION. O~F WELL *t~,~r~ce Leg 1, Slot 2, SMGS Platform "D"; 743~ FSI., 1818~ Fr~/L, Sec. 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. RKB 100' above MSL 8. UNIT, FA~R2VI OR LF, ASE NAME SMGS Unit 9. W~.~.L NO. 4 10. F!~rLD A~ID FOOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 35, TSN, R13~, 8.M. 12. PERMIT I~O.. 67-58 14. Check Appropriate Box To I,ndi'cate N~ature of N~ti'c'e, Report, or Other 'Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURm TREAT JJ~- MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs rlEPAIR WELL CHANGE PLANS (Other) . EUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEI~T* (Other) Perforate and change BHA NoTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dateS, including estimated date of starting any proposed work. 4/21- 4/23/69 4/24- 4/26/69 4/26/69 4/27- 5/8/69 PBTD 10,467' Pulled dual tubing and tandem Kobe BHA. Ran tubing to 10,194' and circulated. Pulled tubing to 9,360'. Made the following additional perforations in the lower Kenai Conglomerate Zone: '~ 10,050 - 10,060', 10,020 - 10,040', 9,980 -10,010', 9,930 - 9,955' 9,870 - 9,890' 9,830 - 9,850' 9,770 - 9,780' 9,740 - 9,750' 9,712 - 9,720' 9,590 - 9 605' 9 570 - 9,580' 9,470 - 9,480' 9,450 - 9,460'; all with 4 JSPF. Pulled single tubing string. Ran dual tubing and single Kobe BHA. Pump tested. 16. I hereby certifyzthp~.-t~e f°re$o~w Is true and correct (This Space fo4~State omce use) Asst. Area Admin. Superviso~ATE TITLE APPROVED BY : CONDXTX~ONS OF APPROVAL, lip AN~:. ::. TITLE See 1,nstrucfions On ReVerse Side DATE 5/16/69 Form REV. 9-30-6? Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION: COMMITTEE SUN:DRY NOTICES AND REPORTS ON WELLS ~Do. n~t use this form for proposals to drill or to deepen or plug back to a dffflerent reservoir. Use "APPLICATION FOR PER1VIIT~" for such proposals.) 5. APl N~CAL CODE 50-133- 20047 6. LEASE DEF~IGNA~ON AND SERLA~ NO. ADL-18746 IL. I ii ' 1. OIL [~ OAS OTHER ~2~ American PeL~o~eum Co~poraLion '~] '~D~ 'oF 'O~AT02 P. O. Box 779, Anchorage, Alaska 99501 &. 'L~CATIO:N O,F WELL At,~face Leg 1, Slot. 2, SMGS Platform "D"; 743' FSL, 1818' FWL, Sec. 35, T8N,R!.3~', S.M. 'i3'.-~VATIONS (Show whether DF, RT, GlO, etc. RKB 100' above MSL '/. IF INDIA_~, A.LLO'A-JV~:~. OR TRI~E NAME 8. UNIT~ FA~/I OR LEASE NAME SMGS Unit 9. W~LL I~O. 4 10. F~r~r~ ~ POOL, OR WII~CAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE O]~JF~'I'IVE) Sec. 35, T8N, R13W, S.M. L2. 'P~IT NO. 67-58 NOTICE OF INTI]NTION TO: TF. ST WATER SHUT-OFF FRACTURE TREAT ~HOOT OR ACIDIZE REPAIR WELL Check AI)propria~e Box TO I,r~lica~ 19ature IUBIIQUINT RIPORT 0f: MULT[PL~ COMPLETE FRACTUR~ TR~ATMffiNT iLT~RING CASING ABANDON* sHOOTING 0R ACZDIZING ABANDONMENT* CHAN~E PLAN~ (Other) (Other) Perforate & change BHA (~OTE: Report results of multiple completion on Well Comp, lotion or Recompletlon Report and Log form.) 15. DE'SCRIBE PRoPosED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, lneludln~ e. timated date of startin$ an~' proposed work. Trip out with tandem BHA. Make the following additional perforations in the lower Kenai Conglomerate Zone: 9450-9460'; 9470-9480'; 9570-9~80'; 9590-9605'; 9712-9720'; 9740-9750'; 9770-9780'; 9830~9850'; 9870-9890'; 9930-9955'; 9980-10,010'; 10,020-10,040'; 10,~50-10,060',; all with 4 JSPF. Trip in with single Kobe BHA. Operation will commence on or about 4/22/69. APR 2 2 !9 o DIVISION OF OIL AND GAS ANCHOrAgE TRM _ OKQ ~ KLV HV,'~< ~ REL FILE le. I'hereb~ eertify~th~eh~ foreeoins I. true and co'eot AS S i S taut Are a ..... ~j~[~~.~~_~ ~ mAdministrative Supervisor 4/21/69 ...... , . - (T~Ipaec for ~ate~usO-- ~ ~ ~ . . - App~cv~d Cop~ ~ ~ru~ions O~ reVe~ Side Returned Form P--7 · SUBMIT IN DUPLIC * STATE OF ALASKA {See other ln- st ructions on OIL AND GAS CONSERVATION COMMITTEE _ I _IL I ii I ....... mTr'~l--I--- WELLCOMPLETION OR RECOMPLETION REPORT AND LOG* WELL WELL DEEP-[] PLUG ~-~ EN BACK L DRY [~] Other DIFF. ~ESVR. ~] Other la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW ~] wonI¢ ~-~ WELL OVER 2. NAME OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR P. 0. Box 779- Anchorage, Al'aska 99501 ~. LOCATION OF WELL (Re~ort locatibn cle~rZy and:in accordance with any State requirements)* At surface ~ At top prod. interval reported below : At total depth 5. AP1 NUNiF2,ICAL CODE 50-133- 2005,7 ~. LEASE DEs[GN~'~fON AND SIERI. A3., NO. ADL- 1875,6 7.IF INDIAN, ALLO~ OR TRIBE NA1VIE 8. UNIT,FA.H~V/ OR LEASE NAi~IE SMGS Unit 9. WELL NO. 10, FIELD ARiD POOL. OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PEHA~ITI~O. 67-58 - I~.OWMANY* ROTARY TOOLS CABLE TOOLS ~.. PRODUCING INTERVAL(S), OF TH/S COMPLETIO~I--/POP, BOTTOM, iN~A1ViE (MD AND TV]))* 23, WAS DIRECTIONAL SURVEY 1VIADE 24. TYPE ELECTRIC AND. OTHEI:t LOGS.RUN CASING SIZE ~ WEIGtIT, _ CASING RECORD (Report all strings set in well) ' ' ' DEPTH SET (MD) HOLE SIZE 26. LINER RECO'~.~, CF~M[L..NTING RECOiR~ i 27. TUBING i AiVIOUNT PULLED u ~ SIZE '! TOP (iV[D) 28. PER~ORATIONS OP~.-~N TO PRODUC BOTTOM (MD) [SACKS CEMENT* rlOAT' (Interval, si!e and number) D.a_TE FIRST PrtODUCTION 5-26-68 , 6-6-68 [ , 24 · [ 124/64" FLOW, ~BING ' ]~$~G P~SS~ ]CAL~~ OI~BBL. ~sed for fuel and flared 32. LIST O~' ATTACHMENTS ~eli Re.ir Hts~o~ SCREEN (MD) SIZE SET (MD) PACKER SET (MD) WELL STATUS (Producing or ~nut-in) W.t~TER--BBL. [ GAS-OIL R.~TIO [ 2 ,[ 313 W~SR--~L. [O~L a~AVIT¥-~ ] , ],, 33.9° ] TE~T WITNESSED BY ""-- " 33.SIGNEDI 'hereby cer tify~, foregoing/and..~'/~~atIa~hed informationTITLElS c0mpl~teAsst.andAreaCOrrectAdmin .as determinedsupYr .fr°m allravallableDATErecords *(See Instructions and Spaces [or Additional Data on Reverse Side) 8-15-68 OIL--BBL. C~S~I~CF. 1062 [ 332 i ii PRODUCTION PRODUCTION 1VIETHOD (Flowh~g, gas lif. t', pumping--size and type of pump) 3-1/2" 10;091' 'I 935,Q' H 29. ACID, S~IOT, FRAL~I'LrHE, CF_~LENT SQUEEZE, ETC. D~-I LNTEI{VAL (MD) I A~{OUNT ZdXFD KIND OF MATE~AL USED INSTRUCTIONS General: This form is designed for submitting a complete and correc! well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate whick~ elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prc.Jucir~g interval, or intervals, 'top(s), bottom(s) and narr,~e (s) (if any) for only the inlelv~! reported in item 30. Submit 'a separate report (page) on this form, adequately identified, for each adctitional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). :i'UMMA.RY OF' FOi:{MATION T~,STS IN('I.,UI)IN(; INTERVAL T~TED, PROCURE DAT~ ~ ~ECOV~I~ OF OIL, OAS. 35. G~GIC MARK~ WAT~ AND MUD NA~ MEAS. 1)~ ~U~ V~I~T, O~a{ .'ORE DATA. AqWACII BRIEF D~CRIPI~ONS OF LITItOLOGY. POROSITY. FRAC~R~. App~NT DIPS AND I)E'I'Ei'I'EI) SIIOWS OF OIL. G~ OR WAT~I. AP1 NUA~ERICAL CODE 50-133 -20047 Form No, P--4 REV. 9-30-67 STATE OF ALASKA SUSMrr IN D~UCAT~ OiL AND GAS CONSERVATION COMMITTEE AtONT'HLY REPORT OF ~DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPEllATOR P. O. ]Box 779 - Anchorage, Alaska 99501 4.LOCA~O~ o,~ wv_z~ Leg 1, Slot 2, SMGS Platform 'D'; 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M. 6. LEASE DESIGNATION AND SERIAL NO. AD1'~-18746 7. IF INDIAN, ALOTTEE OE TRIBE NASIE · 8, I/NIT,F.~:LM OR LEASE NA_ME SMGS Unit 9. XVELL NO. 10. FIF_J~ AND POOL. OR WILDCAT South Middle Ground Shoal 11. SEC., T,, R., M., (BOCCI'OM HOLE OBJECTIVE~ Section 35, T8N, R13W, S.M. 12. PERMIT NO. 67-58 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SI~E, CASING ANT) CEIVIENTING JOBS INCLUDING DEPTH SET AN-D VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CI-I_4_NI~F_~ IN HOL~ CONDITIONS, 1/4 Completed as single zone, dual string,, flowing oil well. 1/1-3 Flow testing. RECEIVED FEB 1 ., :. ;-~; '.. DIVISION OF MINES & MINERALS ANCHORAGE cert~the fore oLug true ~orrect SZGmm -. :TU~ Asst. AreaAdmin. Supvr. ~A','~ 2/12/68 NOTE--Report on this form i~uired for each calendar month, regardless of the status of operations, anO must be file~ in ~plicat~ with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. ,'Form P--7 SUBMIT IN DUPLL S~'ATE OF ALASKA str~eLio~s on OIL AND GAS CONSERV~TION COMMITTEE reverse ii ii I ii i I ..... WELL COMPLETION OR RECOMPLETION REPORT AND LOG* I 1~. TYPE OF WELL: OZL ~ ~S - b. TYPE OF COMPLE~ON: NEW ~ WORK ~ DEEP- ~ PLUG ~ ~VELL OVEg EN BACK gESVR. O~her 2. NA~E OF OPgRATOR Pan ~meric~n ~e~=oleum Gor~r~tion ~P. O~ Box 779/-~C~or~ge, Aiaska 99~01 ~. L-~a~ZO~ qr WrLL~ (Re~or~:toeati6n ctearlE- an&~n ~ccordanO,e with any State requirements) ~,~m-~.:~g'i, 'Slot:Z; s~:ds, rbtfo~TM'~D'; 7~' ~S~.~, -.FWL. Section 3;5, TSar. R15W S.M. At' tO~ prod. interval ~potted below ;:~ }~: ~ a ' ::g~3~, FNL,- 1990' FWL,/:Section 35, TSN, R13W, S.M. At total dep~ 1791~ FNL,:~ 2tS6~, FWL,'~Section~SS, TSN, RiSW, S. ~. 5. AP1 NU1VIE~CAL CODE 50-133-20047 'i~EP~IE ~)ESIGNJk'~ION AND SERLa. L NO. ADL-18746 INDIA.H, ALLO~ OR TRIBI~ NA1VIE 8. UNIT,F.A~dVl OR LEASE NAME SMGS Unit 9. WELL NO, 10. FIJ~LD .adVD POOL, OR WILDCAT soUth Middle Ground Shoal n. SEC., ~., R., M., (BOTTOM HOLm OBOECTXVE) . Sec 35, T8N, R13W, S.M. 122 P~T NO. 67-58 10/27/67-I / i2/10/67,'- Ir '. ~')1/4/68~ [ RKB 100' MSL I 77' MSL 18. TOTAL Dl~F_rl~, 1ViD &/TyD[~ PLUG;- ~ . ~D ~ WVD~. ~L'ff~ ~g., '[ 21. ~INTERVALS 'batb~gD ~Y [ ~ / .- :~{. _ -- -f ].' ~~Y* ~ ROTARY TOOLS ' ~ - " '[ CABLE TOOLS ~. PRODUCING. IN'r~V~(S), OF"rmS COMiTIeS, ~M, N~E (~ A~ ~)* ' '[~.'W~ DIRE~ON~ ,'- ~. - ] SURV~ ~E ~425' - 10,070~ '~D ~ State ~ zone · . [ , Yes :- CASING RECORD (Report all strings set in will) - 9-5/8'" 1:40~ & 4'3~ I s::95:7'1 32'q.'MDI 26" 1, 1995'MD117-1/2"{ 105!5"MD112-1/4"t i! ! ~t A2VIOUNW 1822 sx 1450 sx .,. , ' 3-1/2,' ' 93~4i' ' ,[ 9,~24' 28. PER~O~TIONS OPW-a~l TO PRODUL;rlOl~l''(interval sizeandnumber, ·., ~ 3-1/,Z" ,, 190P8' ,. ,i 9425-30', 9440:50".:9460 70' 9550 70' J r 9580,90, ~9685_95.,, 9720_40, 9750 70, ':'~ 9810-30' 9850-70' 99g0-30' 9965-80' 10, 010-g0~, 10, 040-10, 050~, r10,~070~ 30. ; Pi%ODUCTION ~ DATE FIRST PI~ODUCrI'ION I PRO,DUCT, ION METHO,D (Flowh~.g, gas lift, pump~g--size ~d type of prop) ]WELL STAWS (~oduc~ or [ 3' ~ ' I shut-in) ~ - 12/25/67 [ ~ '- ' Flowing:~ I ~roaucing -- I : / / 0 ' ! Z ~ I ILS-lZ4/64 ~ 1' I I i 390 SS lID/IS IZD - ' Z'/7~ ~ ' ~1. DISPOSIglON O~ O18 (~old, used lot ]uel, vented, etc.) .... ~ .... Flared t Well Hi'~-tolty/ ~$1 ~, Directional Data . 33. I hereby eert~y:that the forego~hg and at~d Information !s c0mplet¢'-~nd eor~[~t as determined from all-available records i j~ _~ .~- I I -~.~,' Instructions and S~ces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lands and leases in Alaska. Item: '16: Indicate which elevation is used as /eference (where not otherwise shown) 'for depth measure- ments, given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc F~reduction from more than one interval zone (multiple completion), so state in itern 20, and in item 22 show the p~c-Jucing interval, or intervals, top(s)~ bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for ~ach addit:~onal inte~ val to be seperately produced, show- lng the acfditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage c~menting and the location of the cementing tool. . Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instrbction ~or items 20 and 22 above) WATER AND MUD None ~ MGS Sand Unit 6603t 628t~ ~ Hemlock 9440' 8962' ., · DATA, A'I'I'ACll BRIEF' DESCRIPITIONS OF' L1TI-IOLOGY, POROSITY, FRACTURES, APPA.R.ENT DIPS AND DE'I~EC'TEI) SltOW.g OF' ()IL, GA.S OR WATEIt. , Chronological History SMGS Unit No 4 Repair 5/13/68 - 5/14-15/68 - 5/20/68 5/21-25/68 5/26/68 - PBTD 10,467'. Skidded in WO rig and pulled tubing. Reran and pulled tubing with Kobe equipment. Re leased WO rig. Skidded in WO rig and rigged up. Ran tubing with Kobe equipment and installed and tested tree. Tubing with 2-7/8" tail pipe set at 10,091', packer set at 9350'. Installed surface equipment. Began pumping on Kobe and recompleted as a pumping oil well. Chronological Well History SMGS Unit No. 4 10/27/67 10/z8/67 to 11/06/67 11/07/67 11/08/67 to 1z/1z/67 lZ/13/67 to 12/26/67 12/27/67 to 1/03/68 :1/04/68 Spudded well. Drilled 12-1/4" hole to 700'. Opened hole to 26" and attempted to run 20" casing. Casing stuck at 331' and unable to retrieve. Cemented at 329' with 625 sacks. Drilled with Dyna-drill 742-900'. Drilled 12-1/4" hole to 2020'. Opened hole to 17-1/2" and set 13-3/8" casing at 1995' with 1822 sacks. Ran Gyro survey to 325'. Drilled 12-1/4" hole to TD 10,550', logged and ran 9-5/8" casing set at 10,515' with 1450 sacks. PBTD 10,467'. Perforated selected intervals 9425' to 10,070'. Ran dual string tubing, and set packer at 9324' with tail pipe landed 10,058'. Rig released and testing. Well completed as single zone, dual string flowing oil well. PAN ~RICAN PETROZ~UM CORPOI~TION ' '"" ' ' Form No. P--4 l:~-~;. 9-30-67 STATE OF ALASKA suBMrr IN D~LZCAr~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF :DRILLING AND WORKOVER OPERATIONS WZLL WELL OTHER 2. NAME OF OPERATOR ~.-API NUACERICA/. CODE 50-133-20047 6. LEASE DESIGNATION AXD SEEIAL NO. ADL - 18746 7. IF INDIAN, ALOTTEE OR TRIBE NASlE 8. U'NIT,FAi:KM OR LEASE Pan American Petroleum Corporation SMGS Unit kDI~ESS oF OPElq2kTOR - ..: 9. %VELL P. O. Box 779 - ~horage, Alaska 99501 4 4.LOCATION O'F Leg 1, Slot 2, SMGS Platform 'D'; 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M. I0. FIELD AND POOL. OR WILDCAT South Middle Ground Shoal 11. SEC., T., R.. I¥I., (BOT'FOR~[ HOLE OBJECTIVE ) Sec. 35, T8N, R13W, S.M. 12. PERMIT NO. 672~ 5~o~' ]3. REPORT TOTAL DI~TH AT END OF MONXX-I, CI-I-A~GES IN HOLE SIZE, CASING ANT) CE1VIENTING JOBS INCLUDING DEPTH SET AND VOLUiViES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JO]PS, JLTNK IN HOLE A.ND SIDE-TI:LACKED HOLE AND ANY OTHER SIGNIFICANT CI4AN-~ES IN HOI..,~ CONDITIONS. 12/31 Flow testing. lZ/1-n lZ/lZ lZ/13-17 12/18 lZ/t9-zo lZ/Zl-Z5 lZ/Z6-30 Drilled 10,140'-10,550' and logged. Set 9-5/8" casing at 10,515' with 2050 sx. Released drilling rig and temporarily suspended. Rigged up workover rig. Perforated intervals between 9425' and 10,070'. in hole. Ran and reran dual tubing. Flow tested and released workover 'rig. Lost 30' gun S~aNE~ ~' '/<~,, ,4f_J ./~ =TUF, A S S ' t. A rea Admin. Supv r. n~.,.~ 1/5/68 NOTE~Report on this form is ~l~ired for each calendar month, regardless of the status of operations, and mu~t l~e file¢l in ~luplicat~ with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No, P--4 REV. 9-3O-6'; STATE OF ALASKA svB~rr m DKPLIC~TE O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPO'RT OF 'DRILLING AND WORKOVER OPERATIONS ~.API NUMERICAL CODE 50-133-Z0047 LEASE DESIGNATION A. ND SERIAL NO. ADL - 18746 1. 7. IF INDI.~,N. ALOTTEE O,'~ TRIBE NAME 0IL ~ GAS [] WELL WELL OTHER 2. NA/VIE OF OP~TOR Pan American Petroleum Corporation 3. ADDREss OF OPERATOR P. O. Box 779 - Anchorage, Alaska 99501 '4. LOCATION O,F WELL Leg 4, Slot 1, SMGS PlatformD; 678' FSL, 1765' FWL, Section 35, T8N, R13W, S.M. 8. LrNIT,F.kl:L%~ OR LEASE NA.ME SMGS Unit 9. %VELL NO 10. FIELD A-ND POOL, OR WILDCAT South Middle Ground Shoal 11. SEC,, T., R, M., (BO'i~I'O,M HOl2g OBJECTIVE) Sec. 35, T8N, R13W, S.M. 12. Pi~q]VIIT NO. 67-58 13. REPORT TOTAL DEPTH AT END OF MONTH, CI4_A2~GES IN HOLE SIZE, CASING A/ND CE!ViENTING JOBSINCLUDING DEPTH SET ANI) VOLLrMES USED, PERFORATIONS, TESTS A1N~D tAESULTS, FISHING JOBS. JUWK IN HOLE A_ND SIDE-TI:LACKED HOLE ANT) A-NY OTHER SIGNIFICANT CI-IA~GES IN HOI.~ CONDITIONS. 11/30 TD 10,140' Drilling. n/1-z 11/2-6 11/7-2,9 TD 700'. Opened hole to 26"; 20" casing stuck at 329' While running to 700'. Set 20" casing at 329' with 625 sx. Drilled 17-1/2" hole to 2020' and set 13-3/8" casing at 1995' with 182Z sx. Drilled 12-1/4" hole 2020-10,140'. · 1.4. I hereby certify that the foregoing ~%/true.ar~ correct, SmN~ ~ _ C ~ ,~l/~-~ ~T~ASs't-AreaAdmin-Supvr-nA,,.~ 12/11/67 , NOTF--Report on this form is re ired for each calendar month, regardles$ of the status of operations, with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form No. STATE OF ALASKA OIL AND- GAS CONSERVATION COMMITTEE Effective: July 1, 1964 Anchorage ADL - 18746 ~ SMGS Unit LESSEE'S MONTHLY REPORT OF OPERATIONS Tke followin~ is a correct report of op~ratio'ns and production (incl~din~ drillir~ and prod~cin~ wells) for the month of .................. .O_c._t_Q_b._e_._r_ ......... 19'b_7__, ' ~l~ent's address P.O. Box 779 ,~ Pan~___. '7'y "'7~ _z_American Petroleum Co~:p. ................................................................... u'ompany .............. ; ............... - .... :-L .................. ............................................ .......... ............. ............. PI, one 272-8471 . --~ ...... Ass't. Area Admirf. Sunvr. ................................................................................... · '~,... e?z,r_, $ ~l,[:l,e ................................................ &"- ..... AND BHL: SE SW 35 10 10 10 10 10 10 10 10 SE NW 35 10 10 10 10,555-1C 942' to 10,215' vith )eve. 215'; p~ 'for~ 0 0 hole rom ilIe op~ 0 0 [ 0 0 ', setting tubing. 473-10, 53 )' and logged. sing at 10,'t 530' lwith 1550 Sx. , 533-10, }55', 'reco~:ered~14'. 55', DST[~i, 10,530-10,555'. and logge :l. Wx'n~R (If none, so state) REd, ARKS (If drilling, depth; tf shut down, o-u~e; d~te and result of teat for gasoline eont~Jat of ~) 0 AP1 50-133-20042 Model K r ted inte rv. 17-1/2" to :l from Le ned hole f etaine r ~ ~ls betw. 2011e ,~ 1, Slot, ['om 12-1 t 10, 48O en 9245 2, SMG~ /4" to 17 -9810'. AP1 50-133-20047 Platform D. 31/2". See NOTE.--There xvere .P....r. 9.~..u...c..t..i?..n......P...a.g.e. .... runs or sales of oil'. ................ ..N.0. ......................... M cu. ft. of gas sold; No runs or Sales of gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and must mont~u I V~ P be filed in duplicate with the Division of Mines & Minerals by the 6th o[ the succeeding . ~e~ ~h r directed. - . NaY 8 1901 OI¥1~tlON OF MINES & MINERAI~ ~,~lr'~..,~A~'-., FORM 470 2-57 PETI OLEUM CORPO ION 1°. O. Box 779 Anchorage, Alaska 99501 October 30, 1967 File: FKK-1430-WF Re: Spud New Well - SMGS Unit No. 4 Director Division of Lands Deparment of Natural Resources State of Alaska 344 Sixth Avenue Anchorage, Alaska Dear Sir' This is to notify you that the subject well was spudded on State Lease ADL-18746 at 1700 hours on October 27, 1967. The surface location of this well is at SE/4, SW/4, Section 35, TSN, 1R13W, S.M. We plan to drill this well directionally to a botto~n hole lo- cation of SE/4 NW/4, Section 35, TSN, R13W, S.M. Yours very truly, F. K. Krebill Area Superintendent cc' Division of Mines & Minerals 3001 l~orcupine Drive Anchorage, Alaska FORM 43'0 2-57 PANAMERICAN PETI OLEUM CORPO ION P. O. Box 779 Anchorage, Alaska 99501 R E C E!V O~tob~ ~o, ~9~ NOV 1 I)1¥1510N OF MINES & MINEii~J.~ File: F~K-1430-WF Director Division o£ Lands Deparment of Natural Resources State of Alaska 344 SEth Avenue Anchorage, Alaska Spud New Well - Dear Sir: This is to notify you that the subject well wa~ spudded on State Lease ADI~-18746 at 1700 hours on October 27, 1967. The surface location of this well is at SE/4, SW/4, Section 35, TSN, RI3W, S.M. We plan to drill this well directionall¥ to a bottom hole lo- cation o£ SE/4 NW/4, Section 35, TSN, R13W, S.M. k~c.c: Division ol ~es & Minerals 3001 Porcupine Drive Anchorage, Alaska Yours very truly, Original Signed By: F. K. KREBILI~~ F. K. Krebill A rea Supe rintendent No, te: The correct surface location of this well is Leg 1, Slot 2 as stated in the original Application for Permit to Drill dated 10/3/67. Please disregard our 10/23/67 letter, FKK- 1384-WF which incorrectly changed the drilling slot to Leg 4, Slot 1. FORM 470 2-57 PANAMERICAN PETROLEUM COI POi kTION P. O. Box 779 Anchorage, Alaska 99501 October 23, 1967 File: FKK-1384-WF Re: SMGS Unit #4 Mr. Thomas R. Marshall, Jr. State of Alaska Division:of Mines &Minerals Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska Dear Sir: Your Permit No. 67-58 to drill the subject well, dated October 3, 1967, shows the surface location of: "Leg 1, Slot 2, SMGS Platform D; 743' FSL, 1818' FWL, Section 35, T8N, R13W, S.M." Due to a change in plans, the surface ~location of SMGS Unit #4 has been changed to: /"~' "Leg 4, Slot%SMGS~f°rm D; 678' FSL, 1765' FWL, Sect~~, T8N, R13W, S.M." All other data on the~iginal ~pplication for Permit to Drill, including the BH~L,-~femains the same. A new "leg and slot diagram" is enclose~~_~r fi~ ~ les. z~ ~i~.~"/~'~/'"~/~ Yours very truly, ,F /~' / ~eaK. Krebill Superintendent Enclosure RECEIVED OCT 25 1967 DIVISION OF MINES & MINEIt, A~ ANCHORAGE FORM SA - I B 125.5M 8/O7 ~' ~ MEMORANDUM state of Alaska SUBJECT~ ~ ~ ~ ~ ~ FORM SA - I B 125.:SM 8/67 MEMORANDUM State of Alaska TO: FiJilij ,~ ~ FROM: DATE SUBJECT: ~ ~ ~ ~ 'jJJ~ FORM SA 125.5M 8/67 ,, -M'EMORANDU,M State of Alaska DATE SUBJECTs i , i 7 N. ~ r=~ r~27 PAN AMERIC AN-- SKELLY-SINCLAIR- PHILLIPS R. 13.W. PAN AMERiCAN-SKELLY SINCLAIR- PHILLIPS R. 13W. 0 Ac. 4160 Ac. 36 Z 8 N, Ne ADL 18744 ADL 1874 6 ADL 18750 · Fe;Jeral ~'leases State "leases 160 Ac:-es Total SOUTH --LEGEND- ,~ ~ ~=, F~, UNIT BOUNDARY TRACT TRACT BOUNDARY NUMBER u All EXHI BlT TO ACCOMPANY Mf r',n[_E G"'""' '~" ' .....;-;'uu~'~ P SHOAL COOK INLET BASIN, ALASKA MILES Form o - ..... ~ ..... STATE OF ALASKA . - OIL AND GAS CONSERVATION COMMITTEE ~o'J3JJ APl 50-133- OOF~. -' SUBMIT IN TR/PLICATE* E££ective: ~uly 1, 1~ {Other instructions on re~erse stde~ LEASE DESIGNATION AND SERIAl, NO APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL IX! "~'(, DEEP£N I'-I-' i' PLUG BACK [-1 b. TYPE OF WELL . ' OIL [] OAS O SIN(tLR[2 MULTIPLE ~ WEL~ WELL OTHER ZONE ZONE NAME OF OPERATOR Pan American Petroleum Corporation ~. ADDRESS OF OPERATOR P. O. Box 779 - Anchorage, Ala,ska 99501 4. ~.OCATXON OF wm~.~ (Report location clearly and in accordance with any State requirements.* ) At surface Leg~, Slot Z, SMGS Platform D; 743'FSL, 1818' EWE, Sec. 35, T8N, R13W, S.M. At proposed prod. zone 1980'FNL, 1980'FWL, Sec..35, T8N, R13W, S.M. ADL - 18746 6, IF INDIAN, ALLOTTEE O~ TalOg NAMI~ 7. UNIT AGREEMENT NAME 8. FARM oB r-EASE NAMm SMGS Unit $. WELL NO. 4 10. FIELD AND POOL, OR WILDCAT South Middle Ground Shoal 14,DISTANCE IN MILER AND DIRECTION FROM NRAREHT TOWN OBFOSTOFFICEe 15-1/2 m~les NNW of Kenai ~oe~xos ~o s~a=s~ 1980' from Unit's ~o PROPERTY OB LEASE LINE, ~. (ALSO to nearest drip. unit line, if any) N line 4160 'i8. DIS~iNcz ~ao~ Pao~os~ LOCATION' ~Q~0~ ~I~ Of 19. PaOPOSED ~PTH 20. aOT~Y Oa Ci~l,m TOOLS TO NEAREST WELL, DRILLINO, COMPLETED.' /~ os ~, ~. o~ ,am =~. ~. SMGS Unit ~2 11,500' ~otary 21. E~va~oms (Show whe~ DF, ET, GR, e~.) Estimated RKB 105' above ~L ~tober 17, 1967 23. PROPOSED CASING AND CEMENTING PROGRAM 20" 600' 17-1/2" 13-3/8" 85~ & 94# 54.5# 2000' 12-1/4" 9-5/8" 40# & 43.5# 10000' 8-5/8" 7" 26// 9800-11, 500' QUANTITY OF CEMEN~ ICir. culate- t-'~-~-~s u rfa c~ ]Circulate to surfs, ce 0'° Fill up from shoe to hange~ 1. Deviation to reach BHL from permanent platform. 2. There are no affected operators. 3. BOP specifications are attached. 4. Intervals of interest will be perforated and may be stimulated. IN ABOVE SPACE DEscaxRE PROPOSED PaooaAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new producttve zone. If proposal is to drill or deepen directionally, ~lve pertinent data on subsurface locations and measured and true vertical depth-s. Give blowout preventer program, if any. _ tha~.heF r~'~e~s True and Correct. ~ 2 ~ ~ I he~y s.~N~D'"~'~ ",/~Z/ '/r--~?'~-' ~ ~d~~ ~.~As.s't. Area Admin. Supvr. ,A~. 10/3~/67. (This space for Federal or S~te o~ee ~ CONDITION~ OF APPROVAb, i~ ANY: ;. THOMAS R. MARSItALL, · A[as~¢ Oil & Gas ~nse~ation Committee *See Instructions On Reverse Side R. 13 W. iI- ~ '-'"-'~'.' 1~ PAN AMERICAN-- ~ ' !~. . [t SKELLY-SINCLAIR- D ~ ii ..... i . D PHILLIPS ~ {~ PA AMERICAN- KELLY- · ' ~- D ' ' ~'~o,S~CLAIR- PHI ~LIPS ' ' T. D ..... ~"L'~' ' ' ~ .... ~ ~4 ~ ~ 35 36 8 N. i .":.'. . -:. . . . . ADZ 18750 D 8 D N. D .: .... ADE: 18744 ~ ADL 187,,46 "~ ADL 187.50 " .... Federal- leases 0 AC. .*leases =4160..Ac. 4160 Acres '" State Total EXHIBIT "A" TO ACCOMPANY SOUTH MIDDLE GROUND SHOAL UNIT AGREEMENT COOK INLET BASIN, ALASKA o I Form P--1 , '.'"~ , ~ '- ': '-' STATE OF ALASKA '"' ":' OIL AND GAS CONSERVATION COMMITTEE ,~A dO~. ' SUBMIT IN TRIPLICATEe (Other instructions on reverse side) APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPSl OF WORK DRILL [] .....' DEEPEN J'"l ' PLUG BACK 1-'-1 TYPE OF WELL ' . . O,L X--'I OAS F--I ''NO"E I---I M'~LT'P'~' I~ WELL WELL OTHER ZONE ZONE NAME OF OPERATOR Pan American Petroleum Corporation 8. ADDRESS OF OPERATOR P. O. Box 779 - Anchorage, Alaska 4. LOCATION O~ WELL (l~elMrt loe~tion clearly and in accordance with any Stat~rt~luif~ments.' )//' - At,urfaee Leg~,.Slot ~, SMGS Platform D; -2~9~/FsL, ~ FWL, '/~/ ' ~' Sec. 35, TSN, R13W, S.M.- At proposed prod. zone 1980' FNL, 1980' FWL, Sec..35, TSN, R13W, S.M. ~4, DISTANCm IN M/LEE AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 15-1/2 miles NNW of Kenai 1'~'~ 2nnf"~°~ APl 50- .....- ....~.j~. ", Effective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO. ADL -'18746 6. IF INDIAN, ALLOTTEE OR THIBm NAME UNIT AGREEMENT NAME · 8. FARM OR LEASE NAME SMGS Unit 9. WELL NO. 4 lO. FIELD ANY) POOL, OR WILDCAT South Middle Ground Shoal SEC., T., E., M., OR BI,K. AND S(!RYEY OB AREA BHL: Sec. 35, TSN, R13W, B.0ROUGH sa J 13. STATE Kenai~ Alas~ ~. DISTANCE fROM PROPOSED* lC. NO. 0~ ACRES IN LEASE ~7. NO, O~ ACRES Af~JSl0NED LOCATION TO NEAREST 1980' from Unit's ~ THIS WgLL PROPERTY OB LEASE LINE, ~. (Also to nearest drlg. unit line, If any) N line 4160 ~ ~D TO NEAREST WELL, DRILLING, COMPLETED.' / . os ~ ,o~, o~ .ms ~s. ~. 8MGS Unit ~2 11, 500~ ~otary 21. B~VA~ONS (Show whe~ DF, RI, O~ e~.) [ 22f APPROX. BATE WORK WILL START* Estimated RKB 105~-above ~L [ ~tober 17, 1957 PROPOSED CASING AND CEMENTING PROGRAM HIZE O~ HOL~ SIZ~ OF CASXNO WEX~HT PER FOOT SETTXNG DEPTH qUANT[~Y OF C~M~N~ 26" 17-1/2" 600' 20" 85# & 94#. 13-3/8" 54.5# 9-5/8" 40# & 43.5# 7" 2000' 12-1/4" 10000' 8-5/8" 9800-11,500' Circulate to surface . . Cir. culate to s.urfa..ce Minimum 500 sx Fill up from shoe to hange~ 1. Deviation to reach BHL from permanent platform. 2. There are no affected operators. 3. BOP specifications are attached. 4. Intervals of interest will be perforated and may be stimulated. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directlonally, give pertinent data on subsurface locations and measured and true vertical depth'8. Give blowout preventer program, If any. 24. I he~y t~t~he~F r~c~ True and correct. s,o~,~~." ~ ' ~ ~~ ~,~Ass't..Area Admin. Supvr. ~,,. 10/3'~ 67 (This space for Federal ;r S~te office ~ . ' .~.."' ". ' APPROVE~ BY '~ _ ~ TITLE~tlJ~ R~rA~; - DATE -. ; .~ , CONDITIONS OF APPaOVAb, Ir ANY; ,, '? a- Alaska Oil & Gas .. ~n~a~tion ~mmittee *See InStructions On Revere Side 27 34 26 35 35 1765' 2 SEWAR3, MER · LEG. NO. I LEG, NO. 2 LAT. 60044' 08.16" LAT, 60° 44' 07.72" LONG. 151° 30' 45.85" L~NG. 151° .30' 44.7,3" Y = 2,463~917 Y.= 2,463,871 X = 229~266 X = 229~319 FROM S.W. COR. ~ROM S.W. (::OR. 743' NORTH ~ 699. NORTH ~ 1818' EAST 1872' EAST T8 N IDIAN ALASKA T 7 N SCALE· LEG. NO. 3 LAT. 60~ 44' 07.08" LONG. 151o 30' 45.~6" Y = 2,463,80'7 .. X = 229,26:5 FROM S.W. COR. 653' NORTH ~ 1818' EAST CERTIFICATE OF SURVEYOR ' LEG. NO. 4 LAT. 60° 44' b752" ~J'-~" 5e"~' LONG. 151° $0' 4.6 94" Y = 2,463,853 X = 2'29~211 FROM S.W. COR. 678' NORTH 1765' EAST I hereby certify that lam properly registered' and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my 'supervision-and that all dimensions and other details are correct. Date '-' " ~ Surveyor SURVEYORS NOTE 26 $5 I"= I000' 2 25 56 I The location of S.M.~3. S. Platform "D" was accomplished · . ' "Co , "E by uSe of U.S.C. & G S stations st" asr Fore and Light", and "Boulder" and C.E.T. 18 (Offset P_ ) FINAL PLAT OF S.M.G.S. PLATFORM "D" LOCATED IN SE I/4 SW I/4, PROTRACTEO SEC, 35, T 8N,RISW,S,M. SURVEYED FOR PAN AMERICAN PETROLEUM CORP. P.O. BOX 779 ANCHORAGE, ALASKA SURVEYED BY E M. LINDSEY & ASSOC. LAND SURVEYORS 8~ CIVIL ENGINEERS 3201 ARCTIC BLVD. i ' '-..-Split A~iPpie i"i w l~ne ~_ fi--~--i";.ll up line 2" Check Vaiva Spool --+---Pipe Rams 4" plug or tgate valve 2"Plu Valve Plug or Gale .Valve .. i-2" Plug Valve on side out t'et Equipment below ~his poinl furnished by Pan 411 - ~ plug Va ive ~'" ' W/ShOO ~ 1 ~ne n-.~de s.'.-;,'Pes w/no . more than 45° bend Blank · line ,~ --+-- 2" plug valve ~_~___ 2" line 2" .-choke i. Ail preventor's to be hydraulically opera'ced from an accumulator which will open and 'close hydri! an %e'asu ~hree ~imes'withoua recharging. 2. All equipment thru which bit must pass ~o have at least as large iD as casing being drilled through. , 3. Kelly cock to be on ?:e!ly from time of 4. Drill pipe s'afety valve eo, ui.valen~ to Shaffer' Mod. 55 or OMSCO, with proper conr, ections, ~o b~ on rig floor at ail ~imes. 5. ~,~1 equipment mentioned abo~e to b'e 5000~ WP or~ro,,ger.= ...... - 6. All connections to be fla~ged. 7, Operating manifold to be in easy -~" · re~,~,, of drillers station w/l remote opera=ing Station. ·